APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41
BEFORE THE
ARKANSAS PUBLIC SERVICE COMMISSION
IN THE MATTER OF THE APPLICATION
OF ENTERGY ARKANSAS, INC. FOR
APPROVAL OF CHANGES IN RATES FOR
RETAIL ELECTRIC SERVICE
)
)
)
)
DOCKET NO. 15-015-U
MINIMUM FILING REQUIREMENT SCHEDULES
SCHEDULES E-1, E-2, E-3, E-4, E-5, E-6, E-9, E-10, E-11.1, E-11.2,
E-13, E-14, E-17
REQUIRED BY APSC RULES OF PRACTICE AND PROCEDURE
APRIL 24, 2015
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41 Schedule E-1
Arkansas Public Service Commission
Minimum Filing Requirements
Balance Sheet-Total Company
Entergy Arkansas, Inc.
Partially Projected Test Year Ended
Docket No. 15-015-U
March 31, 2015
Entergy Arkansas, Inc.
Balance Sheet -Total Company
Assets
(1)
Line
No.
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
(2)
Account
Number
131, 135
136
Descripton
Current Assets
Cash and cash equivalents:
Cash
Temporary cash investments - at cost,
which approximates market:
Total cash and cash equivalents
Total Other Temp Investments
Total Notes Receivable
142
144
146
143
173
182.X01, 182.390
151, 152, 158
154, 163
174.104
182.391
134, 165, 171, 174, 175, 236.X01
123 (except for 123DIP)
128 (except for 128400)
121, 122
124, 128400
(4)
September 30, 2014
Amount (A)(a)
(Thousands)
11,703
11,703
-
Accounts receivable:
Customer
Allowance for doubtful accounts
Associated companies
Other
Accrued unbilled revenues
Total accounts receivable
131,920
(30,463)
32,870
103,306
91,794
329,427
Deferred fuel costs
Fuel inventory - at average cost
Materials and supplies - at average cost
Deferred nuclear refueling outage costs
System agreement cost equalization
Prepayments and other
Total Current Assets
224,267
28,490
161,561
38,489
52,355
846,292
Other Property and Investments, at Cost
Investment in subsidiary companies - at equity
Decommissioning trust funds
Non-utility property - at cost (less accumulated depreciation)
Other
Total Other Property and Investments
(260)
745,144
1,640
15,176
761,700
Property, Plant and Equipment
101 (except 101.1), 102, 105, 106,
114, 114.X01, 253.101, 253.106
101.1
107, 253.107
120.6
120.1, 120.5
108.0, 108.1, 108.220, 108.230,
108.X02, 111, 114.X02, 115,
253.108, 253.111
41
42
43
44
45
46
47
48
49
(3)
Electric
Property under capital leases
Construction work in progress
Nuclear fuel under capital lease
Nuclear fuel
Total Property, Plant and Equipment
Less accumulated depreciation
Net Property, Plant and Equipment
182.39B
182.301, 254.301
189
108.2, 108.X01, 182.3
181, 183, 184, 186
48
Amounts may not add or tie to
other schedules due to rounding.
9,080,352
988
215,255
246,216
51,442
9,594,254
(4,147,088)
5,447,166
Deferred Charges and Other Assets
Regulatory assets:
Deferred Fuel Costs
SFAS 109 regulatory asset - net
Unamort Loss Reacquired Debt
Other regulatory assets
Other Assets and Def Debits
Total Deferred Charges and Other Assets
68,714
26,969
930,276
43,726
1,069,685
Total Assets
8,124,843
E-1 Page 1 of 3
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41 Schedule E-1
Arkansas Public Service Commission
Minimum Filing Requirements
Balance Sheet-Total Company
Entergy Arkansas, Inc.
Partially Projected Test Year Ended
Docket No. 15-015-U
March 31, 2015
Entergy Arkansas, Inc.
Balance Sheet -Total Company
Capitalization and Liabilities
(1)
Line
No.
49
50
(2)
Account
Number
221, 224.9
51
52
53
54
(3)
Descripton
Current Liabilities
Currently maturing long-term debt
-
Notes Payable:
Associated Companies
Other
Total Notes Payable
-
55
56
57
58
234
232
59
60
61
62
63
64
65
66
67
68
69
235
Customer deposits
236 (except for 236.FCO), 236.X03 Taxes accrued
190, 236.FCO, 282.905, 283.181 Accum Deferred Income Tax - Fed
190, 282.906, 283.182
Accum Deferred Income Tax - State
237
Interest Accrued
182.335, 182.390, 254.X01
Deferred Fuel Costs
243
Obligations and Capital Leases
242.309
Pension & Other Postret Liab
System Agreement Cost Equaliz
228.301, 242(except 242.309)
Other
Total Current Liabilities
70
71
72
73
74
75
76
77
78
79
80
81
82
83
84
85
86
87
88
89
90
91
92
93
94
95
96
97
190, 236, 237, 282, 283
190, 282, 283
255
227
254
230
228 (except 228.308)
228.308, 253
252, 253
221
226
224
204
204
201
207, 209, 214
216
98
Amounts may not add or tie to
other schedules due to rounding.
(4)
September 30, 2014
Amount (A)(a)
(Thousands)
Accounts payable:
Associated companies
Other
Total Accounts Payable
194,604
142,733
337,337
113,750
(0)
10,238
10,348
18,520
99,784
350
31,644
621,971
Non-Current Liabilities
Accum Deferred Income Tax - Fed
Accum Deferred Income Tax - State
Accumulated deferred investment tax credits
Obligations under capital leases
SFAS 109 Regulatory Liab - net
Other regulatory liabilities
Decommissioning
Transition to Competition
Accumulated provisions
Pension and other postretirement liabilities
Other
1,715,863
260,541
38,020
83,451
235,804
806,232
4,835
234,929
30,035
Long-term debt:
First Mortgage Bonds
Unamortized Premium - LT Debt
Unamortized Discount - LT Debt
Total Other Long-term Debt
Total Long Term Debt
Pref Stock With Sinking Fund
Total Non-Current Liabilities
1,860,000
(1,192)
283,114
2,141,922
5,551,631
Shareholders’ Equity
Pref Stck w/o SF&Other Min Int
Common Stock
Paid in Capital
Retained Earnings
Accum Other Comp Inc/(Loss)
Less-treasury stock, at cost
Total Stockholders' Equity
116,350
470
588,444
1,245,977
1,951,241
Total Liabilities and Stockholders' Equity
8,124,843
E-1 Page 2 of 3
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41 Schedule E-1
Arkansas Public Service Commission
Minimum Filing Requirements
Balance Sheet-Total Company
Entergy Arkansas, Inc.
Partially Projected Test Year Ended
Docket No. 15-015-U
March 31, 2015
Entergy Arkansas, Inc.
Balance Sheet -Total Company
Reconciliation to Schedule B-3
(1)
Line
No.
(2)
Account
Number
(3)
Account & Descripton
99
100
101
102
103
104
105
106
Reconciliation of E-1 Property to B-3 Plant
B-3 Gross Utility Plant Line 86 Column (3)
B-3 Plant Held for Future Use Line 179 Column (3)
B-3 Electr Plant Acq. Adjustment Line 193 Column (3)
E-17 114X01 - PAA reclass to Util Plt (Cr) Line 34 Column (11)
E-17 253101 - Oth Def - EAI Plant In Service Line 478 Column (11)
E-17 253106 - Oth Def-EAI Un-Unitized Plant Line 479 Column (11)
Charge to Account 1010AM in error corrected in October 2014.
E-1 Electric Plant
107
108
109
B-3 Construction Work in Progress Line 187 Column (3)
E-17 253107 - Oth Def - EAI CWIP Line 480 Column (11)
E-1 Construction Work in Progress
110
111
112
113
114
115
116
117
118
119
120
121
122
B-3 Accumulated Depreciation Line 175 col (3)
B-3 Plant Held for Future Use Line 180 col (3)
B-3 Amort Acquisition Adjustment Line 194 Column (3)
E-17 108260 - AccDep-Removal-Fossil-Contra Line 22 Column (11)
E-17 108261 - AccDep-Removal-Hydro-Contra Line 23 Column (11)
E-17 108262 - AccDep-Removal-Other-Contra Line 24 Column (11)
E-17 1082AM - Cost of Removal - Accrual Line 25 Column (11)
E-17 1082IS - Accu Cost Rmvl Contra EAI Secu Line 26 Column (11)
E-17 108X01 - Reclass 108220 to Reg. Asset Line 27 Column (11)
E-17 114X02 - PAA reclass to AccDepr (Dr) Line 35 Column (11)
E-17 253108 - Oth Def - EAI Accumulated Depr Line 481 Column (11)
E-17 253111 - Oth Def-EAI Accum Amort Line 482 Column (11)
E-1 Accumulated Depreciation
Supporting Schedule
(a) E-17
See E-1 Supporting Schedule
(4)
September 30, 2014
Amount (A)(a)
9,165,896,915
965,381
21,824,442
(93,351,609)
(9,431,048)
(5,553,404)
1,520
9,080,352,198
226,744,538
(11,489,964)
215,254,574
4,188,196,187
178,367
1,860,008
1,784,459
24,450
4,744
(10,592,606)
478,419
59,237,543
(93,351,609)
(478,248)
(253,891)
4,147,087,824
Recap Schedules
(A) B-1-N/A, B-3, B-8, D-1.1-N/A,
F-1.1-N/A, F-1.2
Schedule E-1 is "SEC View" and contains the following SEC adjustments not in other MFR's or Cost of Service in FERC View.
236X01-Taxes Accrued Asset Reclass
30,597
236X03-Taxes Accrued Reclass-Current
(34,790)
236X04-Taxes Accrued Reclass-LT
4,193
-
Amounts may not add or tie to
other schedules due to rounding.
E-1 Page 3 of 3
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41
Arkansas Public Service Commission
Minimum Filing Requirements
Entergy Arkansas, Inc.
Docket No. 15-015-U
Schedule E-1 Supporting Schedule
Balance Sheet - Total Company
Partially Projected Test Year Ended
March 31, 2015
A0000 - Entergy Arkansas Inc.
Balance in Thousands
Line #
1 Total Current Assets
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44
45
46
47
48
49
50
51
Amounts may not add or tie to other
schedules due to rounding.
Amount
131000 - Cash
135974 - Outstanding Checks - Payroll
Total Cash
142010 - Service
Customer
142020 - Customer Care Payments In Susp
142021 - Cust Ar Clearing (Edi)
142022 - Cust Ar Clearing (Refunds)
142025 - Cust Ar Clearing (Aps)
142027 - Cust AR Clearing (Phone Paymts
142999 - Storm Cost Recovery
Customer
144000 - Acc Prov For Uncollect Acc
Allow for Doubtful Accounts
144001 - Mar Reserve-Uncollectible Acct
Allow for Doubtful Accounts
Associated Companies
146000 - A/R - Affiliate
146311 - AR: MSS4
146811 - A/R - Affiliate (Fuel)
146842 - AR - AFFILIATE Misc Rec
146FFR - AR AFFILIATE Financial Rights
Associated Companies
Other
143007 - Arm Customer
143026 - Arm Clearing
143050 - Unbilled Accts Receivable Mar
143074 - MISO Receivable
143076 - Residual Load Receivable
143959 - Etec Co-Owner
143983 - Aecc Co-Owner
143985 - Conway Co-Owner
143987 - Jonesboro Co-Owner
143992 - Osceola Municipal Co-Owner
143995 - West Memphis Utilities Co-Own
Other
Total Accrued Unbilled Revenue 173000 - Accrued Unbilled Revenues
173001 - Unbilled Revenue-Wholesale
Total Accrued Unbilled Revenue
Deferred Fuel Costs
182X01 - Def Fuel Asset Reclass
Deferred Fuel Costs
Fuel Inventory-at average cost
151100 - Fuel Stock - Oil
151300 - Fuel Stock - Coal
151959 - Etec Co-Owner
151983 - Aecc Co-Owner Advances
151985 - Conway Co-Owner Advances
151986 - Epi Co-Owner Advances
151987 - Jonesboro Co-Owner Advances
151989 - Emi Co-Owner Advances
151992 - Osceola Municipal Co-Owner Adv
151995 - West Memphis Co-Owner Advances
152000 - Fuel Stock Exp. Undistributed
158150 - NOX Allowance Inventory
158151 - NOX Seasonal Allowance
Fuel Inventory-at average cost
Total Cash
11,464
239
11,703
130,720
23
1,731
(1,430)
2,090
(15)
(1,198)
131,920
(1,076)
(29,387)
(30,463)
2,844
22,550
7,476
0
(0)
32,870
46,094
186
23,112
27,471
2,862
202
2,507
143
642
16
72
103,306
91,794
0
91,794
224,267
224,267
6,163
61,084
(1,220)
(21,274)
(1,216)
(2,455)
(4,749)
(8,547)
(171)
(608)
1,408
16
58
28,490
E-1 Supporting Schedule Page 1 of 11
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41
Arkansas Public Service Commission
Minimum Filing Requirements
Entergy Arkansas, Inc.
Docket No. 15-015-U
Schedule E-1 Supporting Schedule
Balance Sheet - Total Company
Partially Projected Test Year Ended
March 31, 2015
A0000 - Entergy Arkansas Inc.
Balance in Thousands
Line #
52 Total Current Assets
53
54
55
56
57
58
59
60
61
62
63
64
65
66
67
68
69
70
71
72
73
74
75
76
77
78
79
80
81
82
83 Total Other Prop and Invest
84
85
86
87
88
89
90
91
92
93
94
95
96
97
98
99
100
101 Utility Plant
102
Amounts may not add or tie to other
schedules due to rounding.
Amount
Total
Mat &Cash
Supplies -at avg cost
154000 - Plant Matls And Operating Sup
154300 - Inventory Suspense
154301 - Nuclear Inv Returnd For Repair
154302 - Transmission Reel Deposits
154PAS - General Inventory-Passport
163000 - Stores Expenses Undistributed
Mat & Supplies -at avg cost
Def Nuc & Refuel Outage Costs 174104 - Refueling Outage
Def Nuc & Refuel Outage Costs
Prepayments and Other
134024 - Deposit-Row Transmission
165000 - Prepayments
165004 - Pp Taxes-Regulatory Commis.
165100 - Prepaid Insurance
165101 - Pp Taxes - Franchise - Ar
165143 - Ano#1 Shutdown Costs
165400 - Prepaid Ins Directors&Officers
165403 - Pp Taxes Franchise-La
165506 - Prepaid Dues - INPO
165507 - Prepaid Dues - Nuc Energy Inst
165508 - Prepaid Fees - FEMA
165510 - Prepaid Dues to EEI
165RNT - Prepaid Rent Expense
165SAI - PrePaid Designated Servic-SAIC
171000 - Interest & Dividend Rec
174000 - Misc Current & Accrued Asset
174101 - Unbilled Storm Jobbing Orders
174200 - Unbilled External Jobbng Ordrs
175200 - Derivative Instr - MISO FTRs
236X01 - Taxes Accrued Asset Reclass
Prepayments and Other
Total Current Assets
Invest in Affill - at equity
123100 - Investment In Subsidiary -Equi
123101 - Inv.Assoc.Cos-Arklahoma-Inv.
123105 - Invassoc Cos Arklaho Eqty Ear
123189 - Dividends Rec'd-Consol Affil.
123199 - Investment in Sub - Capital
Invest in Affill - at equity
Decommissioning Trust Funds
128003 - Nuc Decom Val Acct-Qf-Sfas 115
128004 - Nuc Decom Act-Ano2-Qf-Sfas 115
128104 - Decommission Trust Fund-Qual
Decommissioning Trust Funds
NonUtil Prop at cost (less AD)
1210AM - Non Utility Property
122000 - Acc Prv Depr Amrt Nonutl Prp
1220AM - Acc Prv Depr Amrt Nonutl Prop
NonUtil Prop at cost (less AD)
Other
124102 - Capital Avenue Development Co
128400 - Escrow Funds - Sun Trust Bank
Other
Total Other Prop and Invest
Electric
101060 - Asset Retirement Obligat Asset
101061 - ARO Asset-Fossil Steam Product
(21,624)
1,383
664
214
160,527
20,397
161,561
38,489
38,489
20
397
2,473
4,126
85
855
103
271
420
180
560
72
89
(0)
0
10,000
901
748
458
30,597
52,355
846,292
(1,252)
65
134
(1)
795
(260)
124,330
106,261
514,553
745,144
1,757
(106)
(11)
1,640
2,976
12,200
15,176
761,700
110,910
776
E-1 Supporting Schedule Page 2 of 11
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41
Arkansas Public Service Commission
Minimum Filing Requirements
Entergy Arkansas, Inc.
Docket No. 15-015-U
Schedule E-1 Supporting Schedule
Balance Sheet - Total Company
Partially Projected Test Year Ended
March 31, 2015
A0000 - Entergy Arkansas Inc.
Balance in Thousands
Line #
Total Cash
103 Total Current Assets
104
105
106
107
108
109
110
111
112
113
114
Total Prop Under Captial Lease
115
116
117
Construction Work in Progress
118
119
120
Nuclear Fuel Under Cap Lease
121
122
123
Total Nuclear fuel
124
125
126
127
128
Less - Accum Depr and Amort
129
130
131
132
133
134
135
136
137
138
139
140
141
142
143
Utility Plant
144 Tot Def Debits and Oth Assets SFAS 109 Regulatory Asset- net
145
146
147
Unamort Loss Reacquired Debt
148
149
150
Total Other Regulatory Assets
151
152
153
Amounts may not add or tie to other
schedules due to rounding.
Amount
101062 - ARO Assett - Hydro Production
101063 - ARO Asset - Other Production
1010AM - Electric Plant In Service
1010IS - Contra Asset-EAI Sec Ice Storm
1050AM - Plant Held For Future Use
106000 - Completed Projcts Unclassified
114000 - Electr Plant Acq. Adjustment
114X01 - PAA reclass to Util Plt (Cr)
253101 - Oth Def - EAI Plant In Service
253106 - Oth Def-EAI Un-Unitized Plant
Electric
1011LR - Capital Lease Amortization
1011LS - Property under Capital Lease
Total Prop Under Captial Lease
107000 - Constr. Work In Progress
253107 - Oth Def - EAI CWIP
Construction Work in Progress
120600 - Nuclear Fuel-Capital Leases
1206CP - N.F. Cap. Leases (CPD)
Nuclear Fuel Under Cap Lease
120100 - Nuclear Fuel
12017P - Nuclear Fuel-Unpledged (CPD)
12017R - Nuclear Fuel-Unpledged (CRD)
120510 - Spent Fuel Dry Strg Casts Amor
Total Nuclear fuel
1080AM - Accum Prov Depr Plant Service
1080IS - Accu Prov Contra PIS EAI Secur
108100 - Accumulated Depr - Aro Assets
108110 - AccumDeprec-ARO Asset-Fossil S
108111 - Accum Deprec ARO Asset - Hydro
108112 - Accum Deprec-ARO Asset-Other
108220 - Rwip - Removal Cost
108230 - Rwip - Salvage - Scrap
108X02 - Reclass 108220 to Reg. Asset
1110AM - Accum Prov Amort Elec Util Pln
114X02 - PAA reclass to AccDepr (Dr)
115000 - Amort Acquisition Adjustment
253108 - Oth Def - EAI Accumulated Depr
253111 - Oth Def-EAI Accum Amort
Less - Accum Depr and Amort
182301 - Reg Assets - Fas109 - Federal
254301 - Reg Liability-Fas 109-Federal
SFAS 109 Regulatory Asset- net
189000 - Unamortized Loss On Reacq Deb
189CPD - Unamort loss-reacq debt (CPD)
Unamort Loss Reacquired Debt
108260 - AccDep-Removal-Fossil-Contra
108261 - AccDep-Removal-Hydro-Contra
108262 - AccDep-Removal-Other-Contra
1082AM - Cost of Removal - Accrual
7
24
8,721,286
(41,105)
965
374,000
21,824
(93,352)
(9,431)
(5,553)
9,080,352
(559)
1,547
988
226,745
(11,490)
215,255
(726,598)
972,814
246,216
(30,061)
284,233
(209,038)
6,308
51,442
(3,809,121)
4,258
(64,562)
(743)
(4)
(17)
59,238
(54,196)
(59,238)
(314,927)
93,352
(1,860)
478
254
(4,147,088)
5,447,166
102,886
(34,172)
68,714
21,034
5,935
26,969
1,784
24
5
(10,593)
E-1 Supporting Schedule Page 3 of 11
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41
Arkansas Public Service Commission
Minimum Filing Requirements
Entergy Arkansas, Inc.
Docket No. 15-015-U
Schedule E-1 Supporting Schedule
Balance Sheet - Total Company
Partially Projected Test Year Ended
March 31, 2015
A0000 - Entergy Arkansas Inc.
Balance in Thousands
Line #
154 Total Current Assets
155
156
157
158
159
160
161
162
163
164
165
166
167
168
169
170
171
172
173
174
175
176
177
178
179
180
181
182
183
184
185
186
187
188
189
190
191
192
193
194 Current Liabilities
195
196
197
198
199
200
201
202
203
204
Amounts may not add or tie to other
schedules due to rounding.
Amount
Total Cash
Total Other Assets
1082IS - Accu Cost Rmvl Contra EAI Secu
108X01 - Reclass 108220 fr. Accum. Dep
182303 - Gg1 Costs-Under Recvry-Noncurr
18234A - Fed Litigation Consulting Fees
182357 - Reg Asset - 30Yr Retail
18235A - Reg Asset - MISO FTR M-T-M
182362 - Reg Asset - Asset Retire Oblig
182372 - Reg Asset-ARO-Fossil Steam Pro
182373 - Reg Asset - ARO - Hydro Produc
182377 - Reg Asset-ARO-Other Production
182381 - Regulatory Asset SFAS 158
182383 - SFAS158 Reg Asset Offset Pt D
18239C - Under Recovery - Rider CCR
1823AN - ANOR Regulatory Asset
1823FR - Reg asset-property ins. prov.
1823HC - HCM Deferral
1823LC - Reg Asset - Lake Catherine 4
1823M4 - Under Recovery - MISO Rider
1823MD - MISO Cost Deferral
1823MK - MOARK Regulatory Asset
1823SC - MISO Cost Deferral-Retail
Total Other Regulatory Assets
181000 - Unamortized Debt Expense
181CPD - Unamort. Debt Expense (CPD)
181CPI - Unamortized bond insurance
183000 - Preliminary Survey & Invtg Ch
184001 - Operations Vehicle
18400G - Non-Productive Time Gen
184EST - Safety Training Loader
186013 - Employee Purchased Equipment
186263 - Section 263A
186700 - Pooled Equipment - PEICo
186ACL - Non-Expense Accrued Labor
186AM1 - EAI Agric Irrig AMI Load Cntrl
186EMP - Employee Direct Dep-Clearing
186MTM - Mark to Market
186SFC - Misc Def Debit-Sectz Fin Cost
186U29 - Costs Associated With Nfip
Total Other Assets
Tot Def Debits and Oth Assets
Currently maturing LT debt
221999 - Currently Maturing Bonds
2219CP - Current Maturing bonds retired
2219CR - Currently MaturingBonds Issued
224999 - Currently Maturing Other Ltd
2249CP - Current Maturing Otr LTD retir
2249CR - CurrentlyMaturingOT-LTD Issued
Associated Companies
234000 - A/P - Affiliate
234001 - Money Pool Borrowing
234017 - A/P - Restricted Stock
234018 - MISO Intercompany Payable
234019 - Residual Load InterCo Payable
478
59,238
11,033
1,174
9,085
2,353
236,406
6,761
53
252
459,790
29,865
5,798
750
58,567
19,928
1,842
831
3,407
8,341
23,104
930,276
(27,236)
53,147
1,025
122
17
1,689
94
3
1,062
1,609
1,613
10,374
1
61
142
2
43,726
1,069,685
(440,000)
840,000
(400,000)
(47,000)
297,000
(250,000)
(18,507)
(63,677)
(471)
(12,824)
8
E-1 Supporting Schedule Page 4 of 11
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41
Arkansas Public Service Commission
Minimum Filing Requirements
Entergy Arkansas, Inc.
Docket No. 15-015-U
Schedule E-1 Supporting Schedule
Balance Sheet - Total Company
Partially Projected Test Year Ended
March 31, 2015
A0000 - Entergy Arkansas Inc.
Balance in Thousands
Line #
205 Total Current Assets
206
207
208
209
210
211
212
213
214
215
216
217
218
219
220
221
222
223
224
225
226
227
228
229
230
231
232
233
234
235
236
237
238
239
240
241
242
243
244
245
246
247
248
249
250
251
252
253
254
255
Amounts may not add or tie to other
schedules due to rounding.
Amount
Total Cash
Other
Customer Deposits
Taxes Accrued
234711 - AP Bulk Power/System Agreement
234811 - A/P - Affiliate (Fuel)
234842 - AP - AFFILIATE -Misc Rec
234911 - A/P - N.F. Trust Affiliate
234FFR - AP AFFILATE Financial Rights
Associated Companies
232002 - Fuel Suppliers (Control)
232004 - Incentive Comp
232006 - Accrued Payroll
232008 - Severance Liability
232012 - Credit Unions
232016 - Payroll
232019 - Garnishments
232028 - Helping Hands-Customers Contr
232029 - Employee Reward Points
232032 - Gen Acctg Month End Accrual
232036 - Contract Incentives Payable
232053 - Dept. Of Energy-Nuclear Fuel
232058 - A/P Oracle Outstanding Checks
232072 - A/P Accruals - CWIP
232082 - A/P - Co-Owner MISO Credits
232104 - Fuel Coal Accruals
232214 - Purchased Power Accruals
232708 - A/P - Bulk Power
232710 - A/P - Oracle
232711 - Accts Payable-Unclaimed Proper
232801 - Uncashed Payroll Checks
232802 - Stale Dated Payroll Checks
232850 - MISO Transmission Payable
232APD - Invoice trueup-CLEAResult
232BEN - Accrued Employee Benefits
232DCR - Defined Contrib Restoration Pl
232FUA - Fuel Account Purchase Accruals
232JTO - Payable to Joint Trans Owners
232PAS - A/P Unbilled Receipts-Passport
232SAI - A/P - Saic
232STO - Accrued Stock Options
232U03 - Fuel Oil Cost Accruals
232VAC - Accrued Vacation Liability
Other
235001 - Customer Deposits (Active)
235006 - Customer Deposits-Receivable
Customer Deposits
236105 - Non Income Tax Contingency
236111 - Federal Income Tax
236112 - State Income Tax
236113 - Unemployment - Federal
236114 - Unemployment - State
236142 - Ad Valorem
236143 - Ad Valorem Missouri
236147 - Ad Valorem - Ar
(4,208)
(62,610)
124
(32,440)
0
(194,604)
(8,056)
(6,352)
(2,950)
(29)
(0)
14
(0)
(16)
(6)
(20,672)
(444)
0
(2,384)
(23,973)
(0)
(10,248)
(12)
(2,042)
(52,196)
(0)
(182)
(7)
(1,062)
(522)
142
(1)
(2,325)
(141)
(3,621)
(1,119)
(5)
0
(4,523)
(142,733)
(88,750)
(25,000)
(113,750)
(187)
56,362
18,579
(2)
(6)
(544)
(91)
(28,465)
E-1 Supporting Schedule Page 5 of 11
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41
Arkansas Public Service Commission
Minimum Filing Requirements
Entergy Arkansas, Inc.
Docket No. 15-015-U
Schedule E-1 Supporting Schedule
Balance Sheet - Total Company
Partially Projected Test Year Ended
March 31, 2015
A0000 - Entergy Arkansas Inc.
Balance in Thousands
Line #
256 Total Current Assets
257
258
259
260
261
262
263
264
265
266
267
268
269
270
271
272
273
274
275
276
277
278
279
280
281
282
283
284
285
286
287
288
289
290
291
292
293
294
295
296
297
298
299
300
301
302
303
304
305
306
Amounts may not add or tie to other
schedules due to rounding.
Amount
Total Cash
236153 - Franchise Tax-Local
236157 - Franchise Tax - Missouri
236161 - State Sales & Use Tax
236180 - Railcar Tax - Missouri
236181 - Railcar Tax - Wyoming
236183 - Railcar Tax - Arkansas
236200 - Use Tax Accrual
236211 - Arkansas Use Tax Accrual
236240 - Gross Receipts & Sales Tax
236255 - 1% Jefferson County
236260 - Sales Use Tax-Union County AR
236271 - 1% Independence County
236296 - 1% Hot Springs County
236PRT - Accrued Payroll Taxes (All)
236X03 - Taxes Accrued Reclass-Current
Taxes Accrued
Accum Deferred Income Tax -Fed190131 - Ggi-Arrc-Over/Under Rcv-Fed
190151 - Taxable Unbilled Revenue-Fed
190191 - Customer Deposits-Fed
190241 - Deferred Fuel/Gas-Fed
190351 - Uncollect Accts Reserve-Fed
190451 - Incentive-Fed
190881 - ADIT-NOL C/F-TAP-FED - Current
236FCO - FIN48 Fed Current Def Offset
282905 - Tangible Prop Regs-481 Adj-Fed
283181 - Maint/Refueling - Fed
Accum Deferred Income Tax -Fed
Accum Deferred Income Tax - St 190132 - Ggi-Arrc-Over/Under Rcv-St
190152 - Taxable Unbilled Revenue-St
190192 - Customer Depsoits-State
190242 - Deferred Fuel/Gas-St
190352 - Uncollect Accts Reserve-St
190452 - Incentive-State
282906 - Tangible Prop Regs-481-St
283182 - Maint/Refueling - St
Accum Deferred Income Tax - St
Interest accrued
237000 - Interest Accrued
237002 - Int On Customer Deposits
Interest accrued
Deferred Fuel Costs
182335 - Electric Def Fuel Under Reco
182390 - Under-collect of Sys Agree Cts
254X01 - Def Fuel Liab Reclass
Obligations and Capital Leases 243103 - Misc Capital Lease-Current
243205 - River Fuel
Obligations and Capital Leases
Pension & Other Postret Liab
242309 - Non-Qualified Pension SFAS 158
Pension & Other Postret Liab
Other
228301 - Acc Prov-Pen&Ben-Hosp Res-Adj
242000 - Misc Curr & Accrued Liab
242100 - LOC Fees
242111 - MISO Letter of Credit Fees
(7,282)
(6)
(126)
(34)
(18)
(25)
(324)
(2,978)
(2)
(0)
(0)
(0)
(0)
(61)
(34,790)
0
(3,610)
32,147
(0)
(73,391)
5,085
3,470
104,853
(62,991)
(3,203)
(12,596)
(10,238)
(717)
6,385
(0)
(14,577)
1,010
689
(636)
(2,502)
(10,348)
(18,215)
(305)
(18,520)
115,778
108,488
(224,267)
(114)
(99,670)
(99,784)
(350)
(350)
(7,328)
(479)
(89)
(34)
E-1 Supporting Schedule Page 6 of 11
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41
Arkansas Public Service Commission
Minimum Filing Requirements
Entergy Arkansas, Inc.
Docket No. 15-015-U
Schedule E-1 Supporting Schedule
Balance Sheet - Total Company
Partially Projected Test Year Ended
March 31, 2015
A0000 - Entergy Arkansas Inc.
Balance in Thousands
Line #
307 Total Current Assets
308
309
310
311
312
313
314 Total Non-current liabilities
315
316
317
318
319
320
321
322
323
324
325
326
327
328
329
330
331
332
333
334
335
336
337
338
339
340
341
342
343
344
345
346
347
348
349
350
351
352
353
354
355
356
357
Amounts may not add or tie to other
schedules due to rounding.
Amount
Total Cash
242200 - MISO FTRs Payable
242500 - Deferred Revenue - Mar
242CAW - AP Cushman & Wakefield
Total Dividends Declared
Total Tax Collections Payable
Other
Current Liabilities
Accum Deferred Income Tax -Fed190111 - Intrst/Tax-Tax Deficienci-Fed
190121 - ANO Shutdown Costs - Fed
190161 - Property Ins Reserve-Fed
190163 - Capitalized Repairs - Fed
190171 - Inj & Damages Reserve-Fed
190211 - Unfunded Pension Exp-Fed
190213 - SFAS 158 Def Tax Asset - Fed
190215 - Supplemental Pension Plan-Fed
190221 - Fas 106 Other Retire Ben-Fed
190251 - Removal Cost - Fed
190331 - Accrued Medical Claims-Fed
190391 - Contract Def Revenue-Fed
190421 - Environmental Reserve-Fed
190427 - Mark to Market-Oth Contrac-Fed
190465 - Ano Bldg Sale-Fed
190517 - Long-Term Incentive Comp-Feder
190519 - Stock Options - Federal
190523 - Stock Options Exercised-Fed
190525 - Restricted Stock Awards-Fed
190531 - Deferred Director'S Fees-Fed
190603 - Rate Refund-Federal
190609 - Sale Of Epa Allowances - Fed
190613 - Severance Accrual - Federal
190641 - Re-Organization Costs-Federal
190701 - Fas 109 Adjustment - Fed
190884 - ADIT-Tax CR C/F-TAP-Fed-NonCur
190887 - Fed Offset-St NonCur Carryover
190983 - ADIT-NOL C/F TAP-Fed-Non-curr
190P51 - ADIT-Ben-Potnt Disall UTPs Res
236F48 - FIN48
236FNO - FIN48 Fed NonCurrent Def Offst
236N48 - FIN 48 Noncurrent
236X04 - Taxes Accrued Reclass-LT
237191 - Tax Liability
282111 - Liberalized Depreciation-Fed
282117 - Section 481A Adj Fed
282139 - Constr Fund Interest-Fed
282141 - Cost Of Money On Aecc - Fed
282167 - Taxes & Pensions Cap.- Fed
282175 - Afdc Book Only Gross - Fed
282211 - Nuclear Fuel - Federal
282217 - Coal Car - Fed
282221 - Fiber Optics-Fed
282223 - Repairs & Maint Exp - Federal
(2,811)
(0)
(9)
(1,718)
(19,175)
(31,644)
(621,971)
61
(280)
(19,166)
1,014
1,174
(65,592)
150,408
(233)
(16,501)
11,882
2,415
0
408
(770)
45
66
485
627
261
0
112
(10)
10
4,710
28,509
2,323
(5,456)
293,493
200
361,670
(295,815)
(3,511)
4,193
(17,500)
(714,451)
6,381
738
(536)
1,046
(27,491)
(27,724)
(4,821)
(195)
(28,373)
E-1 Supporting Schedule Page 7 of 11
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41
Arkansas Public Service Commission
Minimum Filing Requirements
Entergy Arkansas, Inc.
Docket No. 15-015-U
Schedule E-1 Supporting Schedule
Balance Sheet - Total Company
Partially Projected Test Year Ended
March 31, 2015
A0000 - Entergy Arkansas Inc.
Balance in Thousands
Line #
358 Total Current Assets
359
360
361
362
363
364
365
366
367
368
369
370
371
372
373
374
375
376
377
378
379
380
381
382
383
384
385
386
387
388
389
390
391
392
393
394
395
396
397
398
399
400
401
402
403
404
405
406
407
408
Amounts may not add or tie to other
schedules due to rounding.
Amount
Total Cash
282241 - R&E Deduction - Fed
282245 - Warranty Expense - Federal
282331 - Misc Intangible Plant-Federal
282341 - Interest - Deferred Pay - Fed
282351 - Tax Int (Avoided Cost)-Fed
282371 - Cont In Aid Of Constr - Fed
282381 - Construction Power - Fed
282391 - Ises Book Deprec Cap - Fed
282455 - Business Dev Costs Cap- Fed
282461 - Computer Software Cap - Fed
282475 - Contra Securitization -Federal
282481 - Full Norm Of Prod Plant - Fed
282533 - Casualty Loss Deduction-Fed
282701 - Fas 109 Adjustment - Fed
282901 - 263A Method Change-DSC - Fed
282903 - Units of Production Ded - Fed
282907 - Unit of Property Ded-Trans-Fed
282975 - Depreciation Expense - Fed
283151 - Regulatory Asset - Federal
283157 - Regulatory Asset-MISO-Fed
283213 - SFAS 158 Def Tax Liability-Fed
283221 - Bond Reacquisition Loss - Fed
283225 - Section 475 Adjustment-Fed
283247 - Transco Costs - Federal
283301 - Regulatory Asset-HCM-Fed
283305 - Regulatory Asset-MOARK-Fed
283325 - Tcby Tower (Cadc)-Fed
283345 - Misc Cap Costs-Fed
283357 - Tca - 30 Year Retail - Federal
283361 - Prepaid Expenses Federal
283701 - Fas 109 Adjustment - Fed
283901 - 263A Method Change - Federal
283F48 - FIN 48 adjustment
Accum Deferred Income Tax -Fed
Accum Deferred Income Tax - St 190112 - Intrst/Tax-Tax Deficienci-St
190122 - ANO Shutdown Costs - State
190162 - Property Ins Reserve-State
190164 - Capitalized Repairs - State
190172 - Inj & Damages Reserve-State
190212 - Unfunded Pension Exp-State
190214 - SFAS 158 Def Tax Asset - State
190216 - Supplemental Pension Plan-St
190222 - Fas 106 Other Retire Ben-State
190252 - Removal Cost - State
190332 - Accrued Medical Claims-State
190392 - Contract Def Revenue-State
190422 - Environmental Reserve-State
190428 - Mark to Market-Oth Contract-St
190466 - Ano Bldg Sale-State
190518 - Long-Term Incentive Comp-State
190520 - Stock Options - State
(7,843)
(1,957)
(154)
(273)
9,953
14,540
(6)
(170)
(247)
(17,225)
11,902
(1,629)
(218,040)
(52,188)
(106,206)
(230,245)
(2,287)
3,361
(26,526)
(8,675)
(150,408)
(8,826)
(5,884)
(6,705)
(6,521)
(2,730)
(10,374)
(3,980)
(2,973)
(2,594)
(33,669)
(147,327)
(343,763)
(1,715,863)
12
(56)
(3,807)
371
233
(13,028)
29,875
(46)
(3,278)
2,345
480
0
81
(153)
9
13
96
E-1 Supporting Schedule Page 8 of 11
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41
Arkansas Public Service Commission
Minimum Filing Requirements
Entergy Arkansas, Inc.
Docket No. 15-015-U
Schedule E-1 Supporting Schedule
Balance Sheet - Total Company
Partially Projected Test Year Ended
March 31, 2015
A0000 - Entergy Arkansas Inc.
Balance in Thousands
Line #
409 Total Current Assets
410
411
412
413
414
415
416
417
418
419
420
421
422
423
424
425
426
427
428
429
430
431
432
433
434
435
436
437
438
439
440
441
442
443
444
445
446
447
448
449
450
451
452
453
454
455
456
457
458
459
Amounts may not add or tie to other
schedules due to rounding.
Amount
Total Cash
Accum Def Invest Tax Credits
190524 - Stock Options Excerised-St
190526 - Restricted Stock Awards-State
190532 - Deferred Director'S Fees-St
190604 - Rate Refund-State
190610 - Sale Of Epa Allowances - St
190614 - Severance Accrual - State
190642 - Re-Organization Costs - State
190702 - Fas 109 Adjustment - State
282112 - Liberalized Deprec - State
282118 - Section 481A Adj State
282140 - Constr Fund Interest-St
282142 - Cost Of Money On Aecc - St
282168 - Taxes & Pensions Cap - State
282176 - Afdc Book Only Gross - State
282212 - Nuclear Fuel - State
282218 - Coal Car - State
282222 - Fiber Optics - State
282224 - Repairs & Maint Exp - State
282242 - R&E Deduction - St
282246 - Warranty Expense - State
282332 - Misc Intangible Plant-State
282342 - Interest - Deferred Pay - St
282352 - Tax Int (Avoided Cost) - St
282372 - Cont In Aid Of Constr - State
282382 - Construction Power - State
282392 - Ises Book Deprec Cap - State
282456 - Business Dev Costs Cap- St
282462 - Computer Software Cap - State
282476 - Contra Securitization - State
282482 - Full Norm Of Prod Plant - St
282534 - Casualty Loss Deduction-St
282702 - Fas 109 Adjustment - State
282902 - 263A Method Change - DSC-State
282904 - Units of Production Ded - St
282908 - Unit of Property Ded-Trans-St
282976 - Depreciation Expense - State
283152 - Regulatory Asset - State
283158 - Regulatory Asset-MISO-State
283214 - SFAS 158 Def Tax Liability-St
283222 - Bond Reacquisition Loss - St
283226 - Section 475 Adjustment-St
283248 - Transco Costs - State
283302 - Regulatory Asset-HCM-State
283306 - Regulatory Asset-MOARK-State
283326 - Tcby Tower (Cadc)-St
283346 - Misc Cap Costs-State
283358 - Tca - 30 Year Retail - State
283362 - Prepaid Expenses State
283702 - Fas 109 Adjustment - State
Accum Deferred Income Tax - St
255000 - Accum Def Inv Tax Credit
125
52
0
22
(2)
2
936
5,663
(94,723)
1,268
151
(100)
83
(5,484)
(3,555)
(958)
(39)
(5,657)
(1,548)
(390)
(31)
(51)
2,282
3,900
(1)
(30)
(49)
(3,424)
2,364
(340)
(43,283)
(10,340)
(21,409)
(45,735)
(454)
668
(5,269)
(1,723)
(29,875)
(1,753)
(1,169)
(1,332)
(1,295)
(542)
(2,061)
(791)
(591)
(515)
(6,688)
(260,541)
(38,020)
E-1 Supporting Schedule Page 9 of 11
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41
Arkansas Public Service Commission
Minimum Filing Requirements
Entergy Arkansas, Inc.
Docket No. 15-015-U
Schedule E-1 Supporting Schedule
Balance Sheet - Total Company
Partially Projected Test Year Ended
March 31, 2015
A0000 - Entergy Arkansas Inc.
Balance in Thousands
Line #
460 Total Current Assets
461
462
463
464
465
466
467
468
469
470
471
472
473
474
475
476
477
478
479
480
481
482
483
484
485
486
487
488
489
490
491
492
493
494
495
496
497
498
499
500
501
502
503
504
505
506
507
508
509
510
Amounts may not add or tie to other
schedules due to rounding.
Amount
Total Cash
Obligations Under Cap Leases
Accum Def Invest Tax Credits
227102 - Nuclear Fuel Lease-Non-Curren
227103 - Misc Capital Lease-Non-Curren
2271CR - N. F. Lease-Noncurrent (CRD)
Obligations Under Cap Leases
Other Regulatory Liabilities
254003 - Reg Liab-Qf-Sfas 115-Val Acct
254004 - Reg Liab-Ano 2-Qf-Sfas 115-Val
254016 - Capacity Ridr-Over/Under Recov
254017 - EE Rider - Over/Under Recovery
254309 - Reg. Liab - DOE Settlement
Other Regulatory Liabilities
Decommissioning
230000 - Asset Retirement Obligations
230007 - Asset Retirement Obilig-Fos
230008 - Asset Retirement Obilig -Hydro
230009 - Asset Retirement Obligat-Other
Decommissioning
Accumulated Provisions
228100 - Accum Prov For Prop Insurance
228101 - Int on Accum Prov for Prop Ins
2281FR - Property Ins. Prov. Reclass
228200 - Accum Prov For Injuries & Dam
228210 - Reserve For Inj & Dam - Legal
228400 - Acc Misc-Operating Prov
Accumulated Provisions
Pension & Other Postret Liab
228308 - AccProv-OPEB Liab-FundedStatus
253012 - PensionLiab-Funded Status
253013 - Supplemental Pension Plan
Pension & Other Postret Liab
First Mortgage Bonds
221000 - Bonds
221CPD - Bonds retired (CPD)
221CRD - Bonds Issued (CRD)
First Mortgage Bonds
Unamortized Discount - LT Debt 226000 - Unamortized Disc On L-T Debt
226CPD - Unamort discount-LTD (CPD)
Unamortized Discount - LT Debt
Total Other Long-term Debt
224000 - Other Long Term Debt
224AFB - Other LTD - LR Air Force Base
224CPD - Other LTD Retired (CPD)
224CRD - Other L. T. Debt Issued (CRD)
Total Other Long-term Debt
Pref Stock With Sinking Fund
204999 - Prefrd Stck Issued W/Sink Fund
20499P - Pref St w/S.F. Redeemed (CPD)
Other
252A06 - El Dorado Chemical/Non IPP
252A07 - Little Rock Muni Airport/NonIP
253040 - Oth Def Credits-Source Systems
253118 - Book-Gain On Sale Of Buildings
253270 - L.T. Pay. - (2012-2014 LTIP)
253271 - L.T. Pay. - (2013 - 2015 LTIP)
253272 - L. T. Pay - (2014-2016 LTIP)
253400 - Deferred Credit - Escrow
253401 - Cash Collateral - L.T. Liab.
253F35 - N Little Rock-Galloway Non-IPP
(38,020)
916,294
(875)
(998,870)
(83,451)
(124,330)
(106,261)
(4,717)
(288)
(207)
(235,804)
(797,307)
(8,581)
(81)
(263)
(806,232)
54,649
3,918
(58,567)
(2,525)
(1,064)
(1,247)
(4,835)
(6,989)
(224,781)
(3,160)
(234,929)
(313,507)
978,507
(2,525,000)
(1,860,000)
(375)
1,568
1,192
(483,979)
(2,091)
302,657
(99,700)
(283,114)
(22,027)
22,027
(250)
(161)
(0)
(137)
(93)
(72)
(37)
(12,200)
(9,000)
13
E-1 Supporting Schedule Page 10 of 11
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41
Arkansas Public Service Commission
Minimum Filing Requirements
Entergy Arkansas, Inc.
Docket No. 15-015-U
Schedule E-1 Supporting Schedule
Balance Sheet - Total Company
Partially Projected Test Year Ended
March 31, 2015
A0000 - Entergy Arkansas Inc.
Balance in Thousands
Line #
511 Total Current Assets
512
513
514
515
516
517
518
519
520 Equity Lines
521
522
523
524
525
526
527
528
529
530
531
532
533
534
535
536 Total
Amounts may not add or tie to other
schedules due to rounding.
Amount
Total Cash
Total Non-current liabilities
Pref Stck Without Sinking Fund
Common Stock
Paid in Capital
Retained Earnings
Equity Lines
253F41 - M&A Elect Pwr Coop NON-IPP
253F49 - Paragould LW&Cable Non-IPP
253F63 - Ark Elec Coop Corp./Non IPP
253F65 - Benton Utilities/Non IPP
253F67 - Martin Oper Partners/Non IPP
253F72 - Conway Corp/Non IPP
Regulatory Reserves
Other
204000 - Preferred Stock Issued
204CPD - Pref Stock Redeemed (CPD)
204CRD - Preferred Stock Issued (CRD)
Pref Stck Without Sinking Fund
201000 - Common Stock Issued
Common Stock
207000 - Premium On Capital Stock
207001 - Prem Cap Stk-Common
209000 - Reduction In Value Capital St
214001 - Capital Stock Expense-Common
214CPD - Capital Stock Expense (CPD)
Paid in Capital
216000 - Unappropriated Retained Earn.
216189 - Retained earnings - dividends
Retained Earnings
(43)
(245)
(7,090)
37
(332)
(80)
(344)
(30,035)
(5,551,631)
(101,356)
60,006
(75,000)
(116,350)
(470)
(470)
(251)
(3,214)
(586,783)
50
1,753
(588,444)
(2,009,677)
878,900
(1,130,777)
(1,836,041)
115,200
E-1 Supporting Schedule Page 11 of 11
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41
Arkansas Public Service Commission
Minimum Filing Requirements
Entergy Corporation
Docket No. 15-015-U
Schedule E-1 ETR
Balance Sheet - Total Company
Partially Projected Test Year Ended
March 31, 2015
Entergy Corporation
Balance Sheet - Total Company
Assets
(1)
Line
No.
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
(2)
Account
Number
131, 135
136
134
142
144
146
143
173
182.X01, 182.390
190.X01
190.X02
151, 152, 158, 164
154, 163
174.104
182.391
134, 165, 171, 174, 175, 176, 182, 186
(3)
Descripton
Current Assets
Cash and cash equivalents:
Cash
Temporary cash investments - at cost,
which approximates market:
Total cash and cash equivalents
Accounts receivable:
Customer
Allowance for doubtful accounts
Associated companies
Other
Accrued unbilled revenues
Total accounts receivable
18,190
674
18,864
Deferred fuel costs
Accum Deferred Income Tax - Fed
Accum Deferred Income Tax - St
Fuel inventory - at average cost
Materials and supplies - at average cost
Deferred nuclear refueling outage costs
System agreement cost equalization
Prepayments and other
Total Current Assets
(1,063)
2,268
1,254
92,461
Other Property and Investments, at Cost
Investment in subsidiary companies - at equity
Decommissioning trust funds
Storm Reserve Escrow Account
Non-utility property - at cost (less accumulated depreciation)
Other
Total Other Property and Investments
32
33
34
35
36
37
38
39
101 (except 101.1), 102, 105, 114, 253
101.1
106, 118
107, 118, 253
120.6
120.1, 120.3, 120.5
Property, Plant and Equipment
Electric
Property under capital leases
Natural Gas
Construction work in progress
Nuclear fuel under capital lease
Nuclear fuel
Total Property, Plant and Equipment
41
42
43
44
45
46
47
48
49
50
51
52
Less accumulated depreciation
Net Property, Plant and Equipment
182.3
182.301, 254.301
189
108.2, 108.3
186.2
186.9
190.X04
181, 184, 186
53
Amounts my not add or tie to
other schedules due to rounding.
7,202
8,260
62,878
123 (except for 123DIP)
128
128
106, 121, 122, 253
124, 128
108.0AM, 108.1, 108.220, 108.230
108.X02, 111
1,058
Total Other Temp Investments
Notes Receivable
25
26
27
28
29
30
31
40
(4)
September 30, 2014
Amount (A)(a)
(Thousands)
Deferred Charges and Other Assets
Regulatory assets:
Deferred Fuel Costs
SFAS 109 regulatory asset - net
Unamort Loss Reacquired Debt
Other regulatory assets
Long Term Receivables
Goodwill
Accum Deferred Income Tax- ST
Other Assets and Def Debits
Total Deferred Charges and Other Assets
Total Assets
16,338,981
(7)
16,338,974
3,401
239
3,640
(192)
3,448
20,363
438,080
458,442
16,893,325
E-1 ETR Page 1 of 2
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41
Arkansas Public Service Commission
Minimum Filing Requirements
Entergy Corporation
Docket No. 15-015-U
Schedule E-1 ETR
Balance Sheet - Total Company
Partially Projected Test Year Ended
March 31, 2015
Entergy Corporation
Balance Sheet - Total Company
Capitalization and Liabilities
(1)
Line
No.
54
55
(2)
Account
Number
224.999, 224.9CP, 224.9CR
(3)
Descripton
Current Liabilities
Currently maturing long-term debt
56
57
58
59
233
231
Notes Payable:
Associated Companies
Other
Total Notes Payable
60
61
62
63
234
232
Accounts payable:
Associated companies
Other
Total Accounts Payable
64
65
66
67
68
69
70
71
72
73
74
75
76
77
78
79
80
81
82
83
84
85
86
87
88
89
90
91
92
93
94
95
96
97
98
99
100
101
102
235
236
190, 236, 283.X01
190 283.X02
237
182, 254
243
242
228, 242
190, 236, 237, 282, 283
190, 282, 283
253, 255
227
254
230
228
228, 253
253
221
226
224, 253.025
204
204
201
207, 210, 214
216, 438.100
217
103
Supporting Schedule
(a) E-17-N/A
Amounts my not add or tie to
other schedules due to rounding.
Customer deposits
Taxes accrued
Accum Deferred Income Tax - Fed
Accum Deferred Income Tax - State
Interest Accrued
Deferred Fuel Costs
Obligations and Capital Leases
Pension & Other Postret Liab
System Agreement Cost Equaliz
Other
Total Current Liabilities
Non-Current Liabilities
Accum Deferred Income Tax - Fed
Accum Deferred Income Tax - State
Accumulated deferred investment tax credits
Obligations under capital leases
SFAS 109 Regulatory Liab - net
Other regulatory liabilities
Decommissioning
Transition to Competition
Accumulated provisions
Pension and other postretirement liabilities
Other
(4)
September 30, 2014
Amount (A)(a)
(Thousands)
550,000
2,890,260
776,162
3,666,422
510,549
396
510,945
165,634
163
7,023
2,471
4,902,659
120,722
1,065
16,591
Long-term debt:
First Mortgage Bonds
Unamortized Premium - LT Debt
Unamortized Discount - LT Debt
Total Other Long-term Debt
Total Long Term Debt
Pref Stock With Sinking Fund
Total Non-Current Liabilities
(384)
2,333,456
2,333,072
2,471,450
Shareholders’ Equity
Pref Stck w/o SF&Other Min Int
Common Stock
Paid in Capital
Retained Earnings
Accum Other Comp Inc/(Loss)
Less-treasury stock, at cost
Total Stockholders' Equity
2,548
5,367,769
9,589,903
(5,441,003)
9,519,216
Total Liabilities and Stockholders' Equity
16,893,325
Recap Schedules
(A) B-1 or B-3
B-8, D-1.1
F-1.1, F-1.2 - All N/A
E-1 ETR Page 2 of 2
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41
Arkansas Public Service Commission
Minimum Filing Requirements
Entergy Corporation
Docket No. 15-015-U
Schedule E-1 ETR Supporting Schedule
Balance Sheet
Partially Projected Test Year Ended
March 31, 2015
C0000 - Entergy Corp
Balance in Thousands
Amount
Line #
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44
45
46
47
48
49
50
51
52
Total Current Assets
Total Other Prop and Invest
Utility Plant
Assets
Total Cash
131000 - Cash
131040 - CASH - CITIBANK IPA
Total Cash
Other
136000 - Temporary Cash Investments
Other
Total Notes Receivable
145000 - Notes Rec - Associated Co.
Total Notes Receivable
Associated Companies
146000 - A/R - Affiliate
146001 - Money Pool - Internal Funding
146010 - Inter-Unit Receivable- GL/Misc
146017 - A/R - Restricted Stock
Associated Companies
Other
143007 - Arm Customer
143026 - Arm Clearing
Other
Fed
190X01 - ADIT Fed Current Asset Reclass
Accum Deferred Income Tax -Fed
Accum Deferred Income Tax - St 190X02 - ADIT- ST current asset reclass
Accum Deferred Income Tax - St
Prepayments and Other
165100 - Prepaid Insurance
165400 - Prepaid Ins Directors&Officers
165526 - Prepaid Contract with NYSE
165SAI - PrePaid Designated Servic-SAIC
171000 - Interest & Dividend Rec
Prepayments and Other
Total Current Assets
Invest in Affill - at equity
123100 - Investment In Subsidiary -Equi
123169 - Invest in Sub- Pre 04 Equity
123189 - Dividends Rec'd-Consol Affil.
123191 - Inv in Sub - TAP Settlemt
123196 - Inv in Sub - Noncash
123199 - Investment in Sub - Capital
Invest in Affill - at equity
NonUtil Prop at cost (less AD)
1220AM - Acc Prv Depr Amrt Nonutl Prop
NonUtil Prop at cost (less AD)
Total Other Prop and Invest
Electric
1010AM - Electric Plant In Service
106000 - Completed Projcts Unclassified
Electric
Construction Work in Progress 107000 - Constr. Work In Progress
Construction Work in Progress
Less - Accum Depr and Amort
1080AM - Accum Prov Depr Plant Service
108220 - Rwip - Removal Cost
108230 - Rwip - Salvage - Scrap
Less - Accum Depr and Amort
Utility Plant
Long Term Receivables
186270 - L.T. Rec. (2012-2014 LTIP)
186271 - L.T. Rec. - (2013 - 2015 LTIP)
186272 - L. T. Rec. - (2014-2016 LTIP)
Long Term Receivables
Total Other Assets
181000 - Unamortized Debt Expense
181CPD - Unamort. Debt Expense (CPD)
Amounts may not add or tie to other schedules due to rounding.
1
1,057
1,058
7,202
7,202
62,878
62,878
435
1,275
36
16,444
18,190
1,184
(510)
674
(1,063)
(1,063)
2,268
2,268
57
1,137
59
0
1
1,254
92,461
14,044,633
(12,819)
(6,278,887)
(1,473,150)
1,985,419
8,073,785
16,338,981
(7)
(7)
16,338,974
3,392
9
3,401
239
239
(192)
0
0
(192)
3,448
9,256
7,354
3,753
20,363
(27,495)
43,994
E-1 ETR Supporting Schedule Page 1 of 4
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41
Arkansas Public Service Commission
Minimum Filing Requirements
Entergy Corporation
Docket No. 15-015-U
Schedule E-1 ETR Supporting Schedule
Balance Sheet
Partially Projected Test Year Ended
March 31, 2015
C0000 - Entergy Corp
Balance in Thousands
Amount
Line #
53
54
55
56
57 Current Liabilities
58
59
60
61
62
63
64
65
66
67
68
69
70
71
72
73
74
75
76
77
78
79
80
81
82
83
84
85
86
87
88
89
90
91
92
93
94
95 Total Non-current liabilities
96
97
98
99
100
101
102
103
104
105
186900 - L.T. Assoc. Receivable
186Z99 - Affiliate Advances From
Total Other Assets
Tot Def Debits and Oth Assets
Currently maturing LT debt
224999 - Currently Maturing Other Ltd
2249CP - Current Maturing Otr LTD retir
2249CR - CurrentlyMaturingOT-LTD Issued
Currently maturing LT debt
Associated Companies
233000 - Notes Payable Associated Co
Associated Companies
Other
231000 - Notes Payable
Other
Associated Companies
234000 - A/P - Affiliate
234010 - Inter-Unit Payable - GL/Misc
Associated Companies
Other
232032 - Gen Acctg Month End Accrual
232058 - A/P Oracle Outstanding Checks
232710 - A/P - Oracle
232SAI - A/P - Saic
Other
Taxes Accrued
236105 - Non Income Tax Contingency
236111 - Federal Income Tax
236112 - State Income Tax
236117 - Current Income Tax - Other
236X03 - Taxes Accrued Reclass-Current
Taxes Accrued
Fed
190451 - Incentive-Fed
190455 - Teamshr Over/Under Accrual-Fed
190981 - Fed Offset-State Cur Carryover
283X01 - ADIT Fed Current Liab Reclass
Accum Deferred Income Tax -Fed
Accum Deferred Income Tax - St 190452 - Incentive-State
190456 - Teamshr Over/Undr Accrual-Stat
190882 - Adit-Nol C/F - State-Current
283X02 - ADIT - ST current liab reclass
Interest accrued
237000 - Interest Accrued
237006 - Interest On Bank Loans
Interest accrued
Other
242006 - Accrued Donations-Fas 116-Curr
242100 - LOC Fees
Other
Current Liabilities
Fed
190000 - Accum Deferred Income Taxes
190111 - Intrst/Tax-Tax Deficienci-Fed
190171 - Inj & Damages Reserve-Fed
190341 - Accrued Dues & Contrib-Fed
190381 - Partnership Income/Loss - Fed
190519 - Stock Options - Federal
190523 - Stock Options Exercised-Fed
190525 - Restricted Stock Awards-Fed
190531 - Deferred Director'S Fees-Fed
190871 - ADIT-NOL-SRLY/Dec Fed NonCur
190884 - ADIT-Tax CR C/F-TAP-Fed-NonCur
Amounts may not add or tie to other schedules due to rounding.
402,046
19,535
438,080
458,442
(60,000)
865,000
(1,355,000)
(550,000)
(2,890,260)
(2,890,260)
(776,162)
(776,162)
(8,716)
(501,833)
(510,549)
(66)
(315)
(1)
(14)
(396)
(800)
(8,452)
1,588
(438,908)
280,938
(165,634)
37
(388)
(875)
1,063
(163)
9
(89)
2,349
(2,268)
(6,872)
(151)
(7,023)
(125)
(2,346)
(2,471)
(4,902,659)
(1,924)
(105)
(1)
123
(0)
1,768
(8,001)
(0)
(246)
13,829
21,053
E-1 ETR Supporting Schedule Page 2 of 4
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41
Arkansas Public Service Commission
Minimum Filing Requirements
Entergy Corporation
Docket No. 15-015-U
Schedule E-1 ETR Supporting Schedule
Balance Sheet
Partially Projected Test Year Ended
March 31, 2015
C0000 - Entergy Corp
Balance in Thousands
Amount
Line #
106
107
108
109
110
111
112
113
114
115
116
117
118
119
120
121
122
123
124
125
126
127
128
129
130
131
132
133
134
135
136
137
138
139
140
141
142
143
144
145
146
147
148
149
150
151
152
153 Equity Lines
154
155
156
157
158
190887 - Fed Offset-St NonCur Carryover
190983 - ADIT-NOL C/F TAP-Fed-Non-curr
190990 - Accum Def Inc Tax - Fed
236A11 - Intercompany Tax Agreement
236N48 - FIN 48 Noncurrent
236X04 - Taxes Accrued Reclass-LT
237191 - Tax Liability
282111 - Liberalized Depreciation-Fed
282461 - Computer Software Cap - Fed
283245 - Distribution Maintenance - Fed
283361 - Prepaid Expenses Federal
Accum Deferred Income Tax -Fed
Accum Deferred Income Tax - St 190102 - State DIT-Valuation Allowance
190112 - Intrst/Tax-Tax Deficienci-St
190172 - Inj & Damages Reserve-State
190342 - Accrued Dues & Contr-St
190416 - Lease - Rental Expense - St
190520 - Stock Options - State
190524 - Stock Options Excerised-St
190526 - Restricted Stock Awards-State
190532 - Deferred Director'S Fees-St
190870 - ADIT-St Cap Loss - Non-Current
190891 - Accum Def Inc Tax - State
190982 - NOL Val Allow-State-NonCur
190984 - ADIT-NOL C/F-State-Non-current
190986 - ADIT-Contrib C/F St Non-Cur
190992 - ADIT-State Val Allow-NonCur
282112 - Liberalized Deprec - State
282462 - Computer Software Cap - State
283246 - Distribution Maintenance - St
283362 - Prepaid Expenses State
Accum Deferred Income Tax - St
Unamortized Discount - LT Debt 226000 - Unamortized Disc On L-T Debt
226CPD - Unamort discount-LTD (CPD)
Unamortized Discount - LT Debt
Total Other Long-term Debt
224000 - Other Long Term Debt
224300 - L.T. Credit Borrowings
224CPD - Other LTD Retired (CPD)
224CRD - Other L. T. Debt Issued (CRD)
253025 - Interco Lt Note Pay-Related
Total Other Long-term Debt
Other
253006 - Accrued Donations-Fas116-Noncu
253008 - Oth Def Credits-Director Costs
253800 - Deferred Credit-System Benefit
253801 - Def. Cr. - Syst. Ben-post 2002
Other
Total Non-current liabilities
Common Stock
201000 - Common Stock Issued
Common Stock
Paid in Capital
207000 - Premium On Capital Stock
207800 - Pic-Reacquired Capital Stock
207803 - PIC - Options Tax Benefit
207804 - PIC - Options- Grants
Amounts may not add or tie to other schedules due to rounding.
(130)
1,120,495
754
(988,022)
3,210
(280,938)
(500)
(190)
(785)
(109)
(1,004)
(120,722)
(1,261)
(24)
(0)
28
(0)
325
(1,471)
0
(56)
150
(266)
0
(0)
2,137
(150)
(43)
(179)
(25)
(230)
(1,065)
(682)
1,066
384
(2,775,000)
(245,000)
3,275,000
(1,450,000)
(1,138,456)
(2,333,456)
(225)
(456)
(9,410)
(6,501)
(16,591)
(2,471,450)
(2,548)
(2,548)
(4,946,333)
494,640
(273,832)
(144,203)
E-1 ETR Supporting Schedule Page 3 of 4
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41
Arkansas Public Service Commission
Minimum Filing Requirements
Entergy Corporation
Docket No. 15-015-U
Schedule E-1 ETR Supporting Schedule
Balance Sheet
Partially Projected Test Year Ended
March 31, 2015
C0000 - Entergy Corp
Balance in Thousands
Amount
Line #
159
160
161
162
163
164
165
166
167
168
169
170
171
172
173
174 Total
Retained Earnings
Less-treasury stock, at cost
Equity Lines
Amounts may not add or tie to other schedules due to rounding.
207805 - PIC - Equity Units
207806 - PIC - Restricted Stock Awards
207807 - PIC - LTIP
210000 - Gain Resale Canc Reacq. Stock
214000 - Capital Stock Expense
Paid in Capital
216000 - Unappropriated Retained Earn.
438100 - Dividends Declared By ETR
Retained Earnings
217000 - Reacquired Capital Stock
217100 - Treasury Stock - ETR
217CPD - Reacquired capital stock
217CRD - Reacquired capital stock reiss
Less-treasury stock, at cost
(460,030)
(17,847)
(20,363)
(156)
356
(5,367,769)
(9,220,689)
446,308
(8,774,380)
(208,866)
(1,047,475)
6,728,040
(30,695)
5,441,003
(8,703,693)
815,523
E-1 ETR Supporting Schedule Page 4 of 4
APSC
FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41
Schedule E-2
Arkansas Public Service
Commission
Income Statement - Total Company
Minimum Filing Requirements
Partially Projected Test Year Ended
Entergy Arkansas, Inc.
March 31, 2015
Docket No. 15-015-U
Entergy Arkansas, Inc.
Income Statement - Total Company
(1)
(2)
(3)
Line No.
Account Number
Description
1
2
3
4
5
6
7
Operating Revenues
Domestic Electric:
Retail:
440
442, 442.1
442.2
442.3, 444, 445
8
9
10
11
12
447, 447.3, 447.4, 447.6
447, 447.2, 447.5
447, 447.1, 447.3, 447.5
447, 447.1
13
14
15
16
(4)
6 Months Ended
9/30/14 (a)
(In Thousands)
382,012
245,068
231,207
9,638
Total Retail
867,925
Municipals and Co-ops
Adjoining Utility Systems
Afiiliated
Other Wholesale
859
121,819
66,526
25
Total Wholesale
189,229
Provision for Rate Refunds
Rent from Electric Property
Unbilled Revenues
1,395
2,417
20,826
Other
49,478
18
Total Miscellaneous
74,116
19
Domestic Electric
17
20
21
22
449.1
454, 454.1, 454.2, 454.U
456.2, 456.3
400, 400.4, 413, 414, 449, 450, 451,
455, 456, 457, 459, 459.9
Residential
Commercial
Industrial
Governmental
480, 481, 487, 488, 489, 495, 496.1, 499
442, 456
418.1
Natural Gas
Steam Products
Competitive Business
23
Total Operating Revenues
24
25
Operating Expenses
Operation and Maintenance:
Fuel, fuel-related expenses, and gas
purchased for resale:
26
27
28
29
30
31
32
33
34
501.2, 501.9, 547.1, 547.2
501.1, 547
518, 518.1, 518.2, 518.3, 518.4, 518.5,
518.6
501, 501.1, 501.3, 501.4
804, 804.1
509, 509.1, 557.001, 557.1
557.002, 557.2, 557.3
880.1, 880.2
35
Amounts may not add or tie to
other schedules due to rounding.
Fuel - Gas
Fuel - Oil
Fuel - Nuclear
Fuel - Coal
Gas purchased for resale
Fuel-related expenses
Deferred fuel - electric
Deferred fuel - gas
Total Fuel Rel Exp, Gas Resale
1,131,270
(181)
1,131,089
72,180
763
58,609
107,573
65
(135,337)
103,854
E-2 Page 1 of 2
APSC
FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41
Schedule E-2
Arkansas Public Service
Commission
Income Statement - Total Company
Minimum Filing Requirements
Partially Projected Test Year Ended
Entergy Arkansas, Inc.
March 31, 2015
Docket No. 15-015-U
Entergy Arkansas, Inc.
Income Statement - Total Company
(1)
(2)
(3)
Line No.
Account Number
Description
36
37
38
39
555, 557.4, 588.2, 588.3
517, 519, 520, 521, 523, 524, 525, 528,
529, 530, 531, 532
411.8, 421.2AM, 426.5OT, 500 - 935
(excluding 501, 518, 547, 555, 557
(except 557.000))
40
41
42
Purchased Power
Nuc refueling outage expenses
Operation
Maintenance
Total Other Oper & Maint
403, 403.9, 411.1
408.1, 426.5
43
Decommissioning
Taxes other than income taxes
(4)
6 Months Ended
9/30/14 (a)
(In Thousands)
314,665
22,040
242,962
86,564
329,526
23,667
47,606
Total Oper & Maint
841,358
Depreciation and Amortization
Other regulatory charges - net
Total Deprec & Amort
118,912
(12,387)
106,526
47
Total Operating Expense
947,884
48
Net Utility Operating Income
183,206
49
50
Other Income & Deductions:
Other Income:
44
45
46
51
52
53
54
55
56
403, 403.1, 403.2, 403.3, 403.6, 403.7,
403.9, 404, 404.1, 404.2, 404.3, 406,
407, 407.3, 407.4, 426.5
407, 407.3, 407.4
419.1, 426.5
419, 419.2,419.3, 431
418, 418.1, 418.3
425
421.1, 421.2
408.2, 417.1, 421, 421.3, 426.1, 426.3,
426.4, 426.5
57
58
59
60
61
62
Allow eq funds used dur const
Interest and Dividend Income
Eq in earn of uncons eq affil
Plant Acquistion Adjustment
Gain (loss) on sale
3,476
16,407
-
Other -TOI
(396)
Total Misc - net
(396)
Total Other Income
Interest and Other Charges
419.9, 427, 427.1, 427.2, 427.3, 428,
428.1, 428.9, 429, 429.1, 430.9, 431.9
Interest on long-term debt
430, 430.1, 430.2,430.3, 430.7, 431, 431.1 Other interest - net
426.5, 432, 432.1
Allow bor funds used dur const
19,486
45,316
599
(2,089)
63
Total Interest and Other Charges
64
Income Before Income Taxes
158,866
Income Taxes
(66,889)
65
409.1, 409.2, 410.1, 411.1, 411.4, 431.1,
66
67
Net Income
437, 437.3, 437.9
68
Preferred dividend requirements and other
Earnings Applicable to Common Stock
Supporting Schedules
(a) E-17
See E-2 Supporting Schedule
Amounts may not add or tie to
other schedules due to rounding.
43,825
91,977
3,437
88,541
Recap Schedules
None
E-2 Page 2 of 2
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41
Schedule E-2 Supporting Schedule
Income Statement - Total Company
Partially Projected Test Year Ended
March 31, 2015
Arkansas Public Service Commission
Minimum Filing Requirements
Entergy Arkansas, Inc.
Docket No. 15-015-U
A0000 - Entergy Arkansas Inc.
Balance in Thousands
6 Mos Ended
9/30/14
Line #
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44
45
46
47
48
49
50
51
52
Total Operating Revenues
Amounts may not add or tie to other
schedules due to rounding.
Total Operating Revenues
Residential
Commercial
Industrial
Governmental
Total Retail
Municipals and Co-ops
Adjoining Utility Systems
Afiiliated
440000 - Residential Sales
Residential
442000 - Commercial & Industrial Sales
442100 - Commercial Sales
442110 - Commercial Sales-General
442120 - Commercial Sales-G & M
Commercial
442200 - Industrial Sales
442210 - Industrial Sales - General
Industrial
442300 - Govt & Municipal Sales
444000 - Public Street & Hwy Lighting
445000 - Other Sales To Pub. Authorit
Governmental
447004 - Municipalities &Co-Op Revenues
447300 - Municipalities
447302 - Lepa
447303 - Benton Mun Light & Waterworks
447304 - City Of Campbell
447305 - Conway Corporation
447306 - City Of Hope
447307 - Jonesboro City Water & Light
447308 - City Of North Little Rock
447309 - City Of Osceola
447312 - City Of Prescott
447313 - City Of Thayer
447314 - City Of West Memphis
447401 - Farmers Electric Coop
447402 - Eai Retained Shares In Gg1
447403 - North Arkansas Electric Coop
447404 - Arkansas Electric Coop Corp
447405 - Associatd Electric Coop., Inc.
447600 - East Texas Elec Coop, Inc.
Municipals and Co-ops
447002 - Sales For Resale Non Assoc Co
4470NR - Sales For Resale-Egsi
447201 - Wholesale Revenue Asociated Co
447202 - Wholesale Revenue Non-Associat
447233 - Nonassoc.Cos. - Spot Sales
447501 - Union Electric Company
447502 - Meam
447510 - Eai Retained Shares In Ggns
447516 - Services Rendered ENNEB (7T)
447550 - Opportunity Sales
Adjoining Utility Systems
447001 - Sales For Resale Assoc Co
447110 - Epg - Mtm Power
447114 - Resource Plan Rev - Non JSP
447115 - Resource Plan Rev - Affiliated
447116 - Mississippi Power & Light Co
1,131,089
(382,012)
382,012
(245,068)
245,068
(231,207)
231,207
(4,532)
(5,107)
9,638
867,925
(65)
(245)
(8)
(32)
(449)
(59)
859
(121,812)
(7)
121,819
(38,200)
(416)
E-2 Supporting Schedule Page 1 of 30
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41
Schedule E-2 Supporting Schedule
Income Statement - Total Company
Partially Projected Test Year Ended
March 31, 2015
Arkansas Public Service Commission
Minimum Filing Requirements
Entergy Arkansas, Inc.
Docket No. 15-015-U
A0000 - Entergy Arkansas Inc.
Balance in Thousands
6 Mos Ended
9/30/14
Line #
53 Total Operating Revenues
54
55
56
57
58
59
60
61
62
63
64
65
66
67
68
69
70
71
72
73
74
75
76
77
78
79
80
81
82
83
84
85
86
87
88
89
90
91
92
93
94
95
96
97
98
99
100
101
102
103
Amounts may not add or tie to other
schedules due to rounding.
Total Operating Revenues
Other Wholesale
Total Wholesale
Provision for Rate Refunds
Rent from Electric Property
Unbilled Revenues
Other
447117 - Entergy Power Inc.
447119 - Acc Recvry Chrg Tarriff - Emi
447120 - Acc Recvry Chrg Tarriff - Eai
447191 - Sales For Resale-Ap&L
447192 - Sales For Resale-Mp&L
447193 - Sales For Resale-Lp&L
447196 - Sales For Resale-Nopsi
447197 - Sales For Resale - Egsi
447199 - Seri Ferc Settlement Adj
4471NR - Sales For Resale Assoc-30% Rb
447390 - System Agreement Receipts
447515 - Grand Gulf Retained Shares Rp
Afiiliated
447000 - Sales For Resale
447003 - Transmission Services Other
447005 - Imputed Transmission Revenue
447118 - Entergy Power Inc-Subst Energ
Other Wholesale
449100 - Provision For Rate Refund
Provision for Rate Refunds
454000 - Rent From Electric Property
454010 - Rent from Electric Prop- Affil
454100 - Pole Attachments
454200 - Land
454U99 - Lease Rental Income
Rent from Electric Property
456200 - Unbilled Revenue
456300 - Unbilled Revenue-Wholesale
Unbilled Revenues
400000 - Operating Revenues
400400 - Epg - Mtm Gas
413000 - Exp-Elec Plt Leased To Others
414000 - Other Utility Operating Inc
414604 - Sales-Gas-Non-Assoc
414607 - Sales-Condensate N-Assoc Co
414614 - Sales Crude Oil-N-Assoc Cos
414617 - Sales-Nuclear Fuel - Ap&L
414618 - Sales-Nuclear Fuel - Lp&L
414619 - Sales-Nuclear Fuel - Seri
414621 - Sales -Fuel Oil - A P & L
414622 - Sales -Fuel Oil - L P & L
414623 - Sales -Fuel Oil - M P & L
414624 - Sales -Fuel Oil - Nopsi
414625 - Sales-Fuel Oil-N-Assoc Cos.
414627 - Sales -F/O Additives - Lp&L
414628 - Sales -F/O Additives - Mp&L
414629 - Sales -F/O Additives - Nopsi
449U02 - Cajun Ctoc Non-Payment
450000 - Forfeited Discounts
451000 - Miscellaneous Service Revenue
(120)
(27,790)
66,526
(25)
25
189,229
(1,395)
1,395
(998)
(1,419)
2,417
(20,826)
20,826
(4,879)
(1,797)
E-2 Supporting Schedule Page 2 of 30
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41
Schedule E-2 Supporting Schedule
Income Statement - Total Company
Partially Projected Test Year Ended
March 31, 2015
Arkansas Public Service Commission
Minimum Filing Requirements
Entergy Arkansas, Inc.
Docket No. 15-015-U
A0000 - Entergy Arkansas Inc.
Balance in Thousands
6 Mos Ended
9/30/14
Line #
104 Total Operating Revenues
105
106
107
108
109
110
111
112
113
114
115
116
117
118
119
120
121
122
123
124
125
126
127
128
129
130
131
132
133
134
135
136
137
138
139
140
141
142
143
144
145
146
147
148
149
150
151
152
153
154
Amounts may not add or tie to other
schedules due to rounding.
Total Operating Revenues
455000 - Interdepartmental Rents
456000 - Other Electric Revenues
456001 - Fees-Gust/Ike Securitization
456002 - Distribution Substation Svc.
456003 - MISO Mkt Sch 11 Wholesale Dist
45600N - Nuc Trns Other Electric Rev
456010 - Misc Rec - Ouachita Upgrades
4560MS - Third Party Sales of Inventory
456100 - Miscellaneous Revenue
456101 - Side Lights
456102 - Gia Annual Fees
456103 - Gen Imbal Agree Tarif Penality
456104 - Cwl Transmission Revenue
456105 - Transmisn Service Rev-Non Firm
456106 - Transmission Service Rev-Firm
456107 - Network Transmission Revenue
456108 - Schdlg Syst Control & Dispatch
456109 - Reactive Suppt & Voltage Cntrl
456110 - Ar Gross Receipts Tax
456111 - Non-Firm Transmission Revenue
456112 - Short Term Firm Transm Revenue
456113 - Long Term Firm Transm Revenue
456114 - Load Imbalance
456115 - Transmission Service Rev-Epi
456116 - Transmn Serv Rev-Epi Non Firm
456117 - Reg & Freq Response Trans Rev
456118 - Spinning Reserve Ptp Tran Rev
456119 - Suppl Reserve Ptp Tran Rev
456120 - Fiber Optics
456125 - Facility Charge - Trans Rev
456126 - RTO & ICT Start-up Costs Recov
456127 - RTO & ICT Operations Costs Rec
456136 - MISO Sch 7 Firm PTP - ST
456137 - MISO Sch 7 Firm PTP - LT
456138 - MISO Sch 8 Non-firm
456139 - MISO Sch 9 Network
456141 - MISO Sch 41 Stm Securitization
456142 - MISO Sch 42 Int/AFUDC Amort
456147 - MISO Sch47 Transition Cost Rec
4561A3 - MISO Sch 41 Stm Securit AECC
4561A4 - MISO Sch 42 AECC
4561A6 - AECC MISO Sch 7 PTP-ST
4561A7 - AECC MISO Sch 7 Firm PTP-LT
4561A8 - AECC MISO Sch 8 NonFirm
4561A9 - AECC MISO Sch 9 Network
4561FR - FFR Transm Revenue
456410 - Trans Equal Charges
456420 - Affiliate service fee revenue
456440 - Non-Affiliated Distr Rev-Resid
456441 - Other Revenue-Rep Commercial
456442 - Non-Affiliated Dist Rev-Indust
(95)
(1,251)
41
744
33
190
(0)
(308)
6
33
96
(0)
(953)
(5,219)
(141)
(8,839)
(554)
(321)
(867)
(20,253)
3
(123)
-
E-2 Supporting Schedule Page 3 of 30
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41
Schedule E-2 Supporting Schedule
Income Statement - Total Company
Partially Projected Test Year Ended
March 31, 2015
Arkansas Public Service Commission
Minimum Filing Requirements
Entergy Arkansas, Inc.
Docket No. 15-015-U
A0000 - Entergy Arkansas Inc.
Balance in Thousands
6 Mos Ended
9/30/14
Line #
155 Total Operating Revenues
156
157
158
159
160
161
162
163
164
165
166
167
168
169
170
171
172
173
174
175
176
177
178
179
180
181
182
183
184
185
186
187
188
189
190
191
192
193
194
195
196
197
198
199
200
201
202
203
204
205
Amounts may not add or tie to other
schedules due to rounding.
Total Operating Revenues
456444 - Non-Affiliated Distr Rev-Light
456445 - Non-Affiliated Distr Rev-Gover
456446 - Other Revenue-REP Commercial
456459 - Non-Affiliated Dist Rev-Co Use
456470 - Other Revenues Co-Owners
456500 - Other Elec Rev - Discounts
456600 - Wheeling
456U04 - La Station/Exxon Ph Ii Revenue
456U07 - Nisco Expense Reimbursement
457100 - Services Rendered-Epg(Non-Epg)
457101 - Services Rendered - Eai (Le A)
457102 - Services Rendered-Eli (Le L)
457103 - Services Rendered - Emi (Le M)
457104 - Services Rendered-Enoi (Le N)
457105 - Services Rendered-Seri (Le R)
457106 - Services Rendered - Sfi (Le F)
457107 - Services Rendered-Epg(Billing)
457108 - Services Rendered - Etr (Le C)
457109 - Services Rendered - Eoi (Le E)
45710T - Services Rendered- Eei
45710U - Services Rendered-Egsi (Le G)
457110 - Services Rendered- Epus (Le 0)
457111 - Services Rendered-Trans (2F)
457112 - Services Rendered-Txdis (2G)
457113 - Services Rendered-Eosi (Le 15)
457114 - Services Rendered - Epi (Le 8)
457115 - Services Rendered-Eihl (Le19)
457116 - Services Rendered-Eci (Le 1E)
457117 - Services Rendered-Mhk (Le 1F)
457118 - Services Rendered-Ewo (Le 1H)
457119 - Services Rendered-Epecc(Le 1P)
457131 - MISO Sch 1 Sched/Sys Ctrl/Disp
457132 - MISO Sch 2 Reactive
457177 - Serv Rend by JV to ENT
457188 - Direct Serv Rend by ENT to JV
457199 - Direct costs - assoc. cos.
4571A1 - AECC MISO Schedule 1
4571A2 - AECC MISO Schedule 2
4571X6 - Services Rendered ? X6
457201 - Services Rendered-Eai(Le Eano)
457202 - Services Rendered-Eli(Le E Wfn
457203 - Affiliate Svcs Rendered-Enuco
457204 - Affiliate Svcs Rendered-Enuc
457205 - Services Rendered-Seri (E Ggn)
457206 - Affiliate Svcs Rendered-Rlms
457207 - Affiliate Svcs Rendered-Eni
457208 - Affiliate Svcs Rendered-Tlg
457209 - Services Rendered-Koch (Le 2B)
45720U - Services Rendered-Egsi(E Rbn)
457210 - Services Rendered-Epih (Le 34)
457211 - Services Rendered-Edesr (Le37)
(515)
(3,141)
(444)
(923)
-
E-2 Supporting Schedule Page 4 of 30
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41
Schedule E-2 Supporting Schedule
Income Statement - Total Company
Partially Projected Test Year Ended
March 31, 2015
Arkansas Public Service Commission
Minimum Filing Requirements
Entergy Arkansas, Inc.
Docket No. 15-015-U
A0000 - Entergy Arkansas Inc.
Balance in Thousands
6 Mos Ended
9/30/14
Line #
206 Total Operating Revenues
207
208
209
210
211
212
213
214
215
216
217
218
219
220
221
222
223
224
225
226
227
228
229
230
231
232
233
234
235
236
237
238
239
240
241
242
243
244
245
246
247
248
249
250
251
252
253
254
255
256
Amounts may not add or tie to other
schedules due to rounding.
Total Operating Revenues
Total Miscellaneous
Domestic Electric
Natural Gas
Steam Products
457212 - Services Rendered-Eami (Le 3C)
457213 - Services Rendered-Ehi (Le 45)
457214 - Services Rendered-Ekel (Le 48)
457215 - Services Rendered-Epihc(Le 4A)
457216 - Services Rendered-Niw (Le 4H)
457217 - Services Rendered-Ewoml(Le 4L)
457218 - Services Rendered-Ethcp(Le 60)
457219 - Services Rendered-Etc (Le 62)
457220 - Services Rendered-Etllc(Le 66)
457221 - Services Rendered-Ebsll(Le 67)
457222 - Services Rendered-Enht(Le 69)
457223 - Services Rendered-Etuno(Le 6A)
457224 - Services Rendered-Envy (Le 72)
457225 - Services Rendered-Egi (Le 76)
457226 - Services Rendered-Epxhc(Le 82)
457227 - Services Rendered-Enfc (Le 86)
457228 - Services Rendered-Eei8B(Le 8B)
457229 - Services Rendered-Epg (Le 8B)
457230 - Services Rendered-Eeidv(Le 8D)
457231 - Services Rendered-Eowex(Le 8X)
457232 - Services Rendered-Epi (Le 9)
457288 - Indirect Ser Rend by ENT to JV
457299 - Indirect costs - assoc. cos.
457708 - Services Rendered-Esi (Le S)
459000 - Company Use
459901 - Conversion Services Revenue
Other
480000 - Residential Gas Sales
481000 - Commercial & Indus Gas Sales
481100 - Commercial Gas Sales
481110 - Commercial Gas Sales - General
481120 - Commercial Gas Sales - G&M
481200 - Industrial Gas Sales
481210 - Gen Serv/Air Cond/Lrg Gas Etc
481300 - Gov't & Municipal Gas Sales
487000 - Forfeited Discounts-Gas
488000 - Miscellaneous Serv Gas Revenue
489000 - Revenue From Trns Of Gas & Oth
489200 - Transp Of Gas To Gen Station
489300 - Transp Of Gas To Gen Sta-Mch
495000 - Other Gas Revenues
495300 - Unbilled Gas Revenue
496100 - Provision For Rate Refund Gas
499000 - Revenue Suspense
Natural Gas
442U00 - Stm. Prod. Sales-El. Exxon
442U02 - Stm. Prod.-Spds Gas Exxon
456U05 - Misc Steam Revenues
456U06 - Stm. Prod. Sales-Exxon
49,478
74,116
1,131,270
-
E-2 Supporting Schedule Page 5 of 30
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41
Schedule E-2 Supporting Schedule
Income Statement - Total Company
Partially Projected Test Year Ended
March 31, 2015
Arkansas Public Service Commission
Minimum Filing Requirements
Entergy Arkansas, Inc.
Docket No. 15-015-U
A0000 - Entergy Arkansas Inc.
Balance in Thousands
6 Mos Ended
9/30/14
Line #
257 Total Operating Revenues
258
259
260
261
262
263
264
265
266
267
268
269
270
271
272
273
274
275
276
277
278
279
280
281
282
283
284
285
286
287
288
289
290
291
292
293
294
295
296
297
298
299
300
301
302
303
304
305
306
307
Amounts may not add or tie to other
schedules due to rounding.
Total Operating Revenues
Competitive Business
Steam Products
400350 - Epg - Operating Revenue Gas O
414100 - Sales - Nuc Fuel - Pilgrim
414101 - Sales - Nuc Fuel - Ip3
414102 - Sales - Nuc Fuel - Fitzpatrick
414103 - Sales Nuclear Fuel - Ip2
414104 - Sales - Nuc Fuel - Vy1 (72)
414105 - Sales?NUC Fuel?Palisades (NA)
417001 - Eei Svcs Rendered-Associated
417098 - Operating Revenue-Epg
417099 - Operatinrevenue-Retail Service
418100 - Equity Earnings Subs Cos
418102 - Equity Earn In Entkoontz (1S)
418180 - Equity In Earn Of Subs - Egsi
418181 - Equity In Earn Of Subs - Eai
418182 - Equity In Earn Of Subs -Eli
418183 - Equity In Earn Of Subs - Emi
418184 - Equity In Earn Of Subs-Enoi
418185 - Equity In Earn Of Subs - Eei
418186 - Equity In Earn Of Subs - Epi
418187 - Equity In Earn Of Subs - Epdc
418188 - Eqty In Earn Of Subs - Ent Arg
418189 - Equity In Earn Of Subs-Seri
41818A - Equity In Earnings Of Sub Eosi
41818B - Equity Earn Of Sub-Epmi
41818C - Equity Earn Of - Epic
41818D - Eqty In Earnings Of Subs -Epoc
41818E - Equity Earn Of Sub - Ers
41818F - Equity In Earnings Of Sub Eni
41818G - Equity Earn Of Sub-Epeh
41818H - Equity In Earnings Of Enhc2
41818I - Equity Earn Of Sub-Ethc
41818J - Equity In Earnings Of Erhc
41818K - Equity In Earn Of Subs-Epxhc
41818L - Equity Earn Of Sub-London Elec
41818M - Equity In Earn Of Sub - Epghc
41818N - Equity Earn Of Sub-Eih Ltd
41818P - Equity In Earnings - Engch-1
41818Q - Equity Earnings-Ent Bus Soluti
41818R - Earnings In Epe&C
41818S - Earnings In Entergy Resources
41818T - Equity In Earnings Of Sub-Evhc
41818U - Equity In Earn Of Subs - Epg
41818V - Equity In Earn In Subs - Epusa
41818W - Equity In Earnings - Etllc
41818X - Equity In Earnings - Ebsll
41818Z - Eqty Ern Of Sub-Ent Transnr Sa
418190 - Eqty In Earn Of Subs-Etsa, Ltd
418191 - Equity In Earnings Of Sub-Egth
418196 - Eqty In Earn Of Subs - Ent Sa
41819A - Equity In Earnings - Ewomh
181
-
E-2 Supporting Schedule Page 6 of 30
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41
Schedule E-2 Supporting Schedule
Income Statement - Total Company
Partially Projected Test Year Ended
March 31, 2015
Arkansas Public Service Commission
Minimum Filing Requirements
Entergy Arkansas, Inc.
Docket No. 15-015-U
A0000 - Entergy Arkansas Inc.
Balance in Thousands
6 Mos Ended
9/30/14
Line #
308 Total Operating Revenues
309
310
311
312
313
314
315
316
317
318
319
320
321
322
323
324
325
326
327
328
329
330
331
332
333
334
335
336
337
338
339
340
341
342
343
344
345
346
347
348
349
350
351
352
353
354
355
356
357
358
Amounts may not add or tie to other
schedules due to rounding.
Total Operating Revenues
41819B - Equity In Earnings - Eptbh
41819C - Equity In Earnings - Enhc#3
41819D - Eqty In Earnings Of Subs-Egpoc
41819E - Equity In Earnings - Enhc
41819F - Equity In Earn-Enfhi (7F)
41819G - Equity In Earnings - Etuno
41819H - Equity In Earnings-EDEHL (2K)
418200 - Esa Earnings
418205 - Esa Earnings
418220 - Etsa Earnings
418300 - Eqty In Earn-Citipower Tr
418301 - Eqty In Earn-Ent Lon Invest
418302 - Eqty In Earn-Euk Ltd
418303 - Eqty In Earn-Epg Cayman Ii
418304 - Eqty In Earn-Eii 1-Min Int
418305 - Eqty In Earn-Eii2
418306 - Eqty In Earn-Eihl
418307 - Eqty In Earn-Eil Td
418308 - Equity In Earnings-Euk Holding
418309 - Eqty In Earn-Citipower Pty
418310 - Eqty In Earn Of Evldc
418311 - Eqty In Earn-Eii 1
418312 - Eqty In Earn-Edesur
418313 - Eqty In Earn-Epg Cayman I
418314 - Equity In Earnings - Evhldc
418315 - Equity In Earnings Of Enhc2
418320 - Epohl Earnings
418325 - Edob Earnings
418331 - Ehl Earnings
418343 - Etc Earnings
418346 - Earnings In Encm 1(7P)
418347 - Earnings In Enip2 (7A)
418348 - Earnings In Encm 2 (7Q)
418349 - Earnings In Envy (72)
418357 - Eqty In Earn-Ent Security Sub
418358 - Entergy Hyperion-Little Rock
418359 - Entergy Hyperion-Jackson
418360 - Entergy Hyperion-Baton Rouge
418361 - Entergy Hyperion-Shreveport
418362 - Entergy Hyperion-Lafayette
418363 - Entergy Hyperion-Memphis
418364 - Sub Earnings Nehpcl
418365 - Sub Earn Minority Intereste In
418700 - Epal Earnings
418710 - Epop Earnings
418711 - Epop Earnings-Minority Interes
440100 - Retail Revenue-Residential
442130 - Retail Revunue - Commercial
442220 - Retail Revenue - Industrial
444100 - Retail Rev-Public St&Hwy Light
445100 - Retail Rev-Oth Sales To Pub Au
-
E-2 Supporting Schedule Page 7 of 30
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41
Schedule E-2 Supporting Schedule
Income Statement - Total Company
Partially Projected Test Year Ended
March 31, 2015
Arkansas Public Service Commission
Minimum Filing Requirements
Entergy Arkansas, Inc.
Docket No. 15-015-U
A0000 - Entergy Arkansas Inc.
Balance in Thousands
6 Mos Ended
9/30/14
Line #
359 Total Operating Revenues
360
361
362
363
364
365
366
367
368
369
370
371
372
373
374
375
376
377
378
379
380
381
382
383
384
385
386
387
388
389
390
391
392
393
394
395
396
397
398
399
400
401
402
403
404
405
406
407
408
409
Amounts may not add or tie to other
schedules due to rounding.
Total Operating Revenues
44700N - Associated Sales To Nonregs
44700R - Associated Sales To Regs
447500 - Other Utilities
4475CA - Capacity sales - affiliates
4475CC - Conterparty Capacity Sales
4475CM - Market Capacity Sales
4475EC - Counterparty Energy Sales
4475EM - Market Energy Sales
4475NR - Sales For Resale-Competiti Bus
447901 - Wholesale Electric Revenue
447902 - Wholesale Steam Revenue
447903 - Epg - Mtm Power
447904 - Revenue-Hedging Activities
447905 - Ppa Amortization
447906 - Energy & Capacity Revenues
447907 - Ip2-Deferred Rev-Wholesale
447908 - Vy-Deferred Rev-Wholesale
447909 - Factoring Revenues
447910 - Amortization of option premium
447911 - Hedging - ineffectiveness
450100 - Forfeited Discounts - Retail
451100 - Miscellaneous Revenue-Retail
456121 - Conver Srvc Rev Power-EWOM
456122 - Conversion Sr Power-Ppg
456123 - Conversion Sr Steam - Lyondell
456124 - Conversion Sr Steam - Ppg
456128 - Conversion SR Steam-Arch Chem
456900 - Beco Revenue
456901 - Conversion Serv Revenue-Epdc
456902 - Misc Revenue - Nonregs
456903 - Heat Rate Corr Factor-Ewom 4L
456904 - Heat Rate Corr Factor-Ppg
456905 - Gas Sales-OBA settle affil
456906 - Ancillary Svcs revenue-affil
456907 - EMA-ISO fee revenue-affil
456908 - Station Svc sales-affil
457000 - Services Rendered-Affiliates
4571XU - Services Rendered - XU
457300 - Services Rendered-Eiltd (Le22)
457301 - Services Rendered-Enuc (Le 80)
457302 - Services Rendered-Enip3(Le 77)
457303 - Services Rendered-Enfz (Le 78)
457304 - Services Rendered-Eni (Le 14)
457305 - Services Rendered-Tlgs (Le 84)
457306 - Services Rendered-Enuc (Le 57)
457307 - Affiliate Serv Rendered - 7A
457308 - Services Rendered Evy
457401 - Services Rendered-Esltd(Le 95)
457402 - Services Rendered-Esslt(Le 96)
457403 - Services Rendered-Erlms(Le 93)
457404 - Services Rendered-Esols(Le 9A)
-
E-2 Supporting Schedule Page 8 of 30
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41
Schedule E-2 Supporting Schedule
Income Statement - Total Company
Partially Projected Test Year Ended
March 31, 2015
Arkansas Public Service Commission
Minimum Filing Requirements
Entergy Arkansas, Inc.
Docket No. 15-015-U
A0000 - Entergy Arkansas Inc.
Balance in Thousands
6 Mos Ended
9/30/14
Line #
410 Total Operating Revenues
411
412
413
414
415
416
417
418
419
420
421
422
423
424
425
426
427
428
429
430
431
432
433
434
435
436
437
438
439
440
441
442
443
444
445
446
447
448
449
450
451
452
453
454
455
456
457
458
459
460
Amounts may not add or tie to other
schedules due to rounding.
Total Operating Revenues
457405 - Services Rendered-Esel (Le 9E)
457406 - Services Rendered-Etri (Le 94)
457407 - Services rendered - Warren
457408 - Services Rendered- Egpo (Le 0)
457409 - Services Rendered - EKT
457410 - Svc Rendered-Ent Koontz (1S)
4574H0 - Services Rendered- Niw (Le 4H)
457500 - Services Rendered-Epg(Non-Epg)
457501 - Services Rendered-Epg(Billing)
457514 - Svces Rendered-EDEHL (LE 2K)
457515 - Services Rendered- Eosi(Le 15)
457516 - Services Rendered-EDEMS(LE 6E)
457517 - Services Rendered-ESDEL(LE 6H)
457518 - Svces Rendered-ESDEL (LE 6H)
457519 - Services Rendered- Eihl(Le 19)
45751B - Services Rendered - Eri (1B)
45751C - Services Rendered-Evhc (Le 1C)
45751D - Services Rendered-Mhki (Le 1D)
45751E - Services Rendered- Eci (Le 1E)
45751F - Services Rendered-Mhk(Le 1F)
45751H - Service Rendered-Ewo (Le 1H)
45751P - Services Rendered-Epecc(Le1P)
45751Q - Services Rendered - Epech (1Q)
457522 - Services Rendered-Eil (Le 22)
45752B - Services Rendered-Koch (Le 2B)
45752F - Services Rendered-Transco(Le2F
45752G - Services Rendered-Etxi (Le 2G)
457534 - Services Rendered-Epih (Le 34)
457537 - Services Rendered- Epeh(Le 37)
45753C - Services Rendered-Eam (Le 3C)
457545 - Services Rendered-Ehi (Le 45)
457548 - Services Rendered-Euke (Le 48)
45754A - Services Rendered-Epih (Le 4A)
45754H - Services Rendered-Niw(Le 4H)
45754L - Services Rendered-Ewoml(Le 4L)
457560 - Services Rendered-Ethc (Le 60)
457562 - Services Rendered-Etc (Le 62)
457566 - Services Rendered-Etll (Le 66)
457567 - Services Rendered-Ebsl (Le 67)
457569 - Services Rendered-Enh1 (Le 69)
45756A - Services Rendered-Uno (Le 6A)
457572 - Services Rendered-Envy(Le 72)
457576 - Services Rendered-Egi (Le 76)
45757F - Services Rendered - Nfnh (7F)
457580 - Services Rendered-Eei2 (Le 8)
457582 - Services Rendered-Epxhc(Le 82)
457586 - Services Rendered-Enfc (Le 86)
45758B - Services Rendered-Eei8B(Le 8B)
45758D - Services Rendered-Eeidv (Le8D)
45758F - Services Rendered-Epgash (8F
45758G - Services Rendered-Epgaso (8G)
-
E-2 Supporting Schedule Page 9 of 30
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41
Schedule E-2 Supporting Schedule
Income Statement - Total Company
Partially Projected Test Year Ended
March 31, 2015
Arkansas Public Service Commission
Minimum Filing Requirements
Entergy Arkansas, Inc.
Docket No. 15-015-U
A0000 - Entergy Arkansas Inc.
Balance in Thousands
6 Mos Ended
9/30/14
Line #
461 Total Operating Revenues
462
463
464
465
466
467
468
469
470
471
472
473
474
475
476
477
478
479
480 Total Operating Expenses
481
482
483
484
485
486
487
488
489
490
491
492
493
494
495
496
497
498
499
500
501
502
503
504
505
506
507
508
509
510
511
Amounts may not add or tie to other
schedules due to rounding.
Total Operating Revenues
Total Operating Revenues
More & hidden
Total Operating Revenues
Total Operating Expenses
Fuel - Gas
Fuel - Oil
Fuel - Nuclear
Fuel - Coal
45758H - Services Rendered - Eptc (8H)
45758M - Services Rendered - Epous (Le
45758X - Services Rendered-Ewoex(Le 8X)
457590 - Services Rendered- Epi (Le 9)
4575XR - Services Rendered-EPOUKL (XR)
457800 - Service Rendered ENNEB 7T
457801 - Services Rendered EKH III 4D
457999 - Services Rendered - Unbilled
458000 - Other Rev-Serv To Non-Associat
48800N - Gas Revenue
48800R - Gas Revenue - Regulated
48800S - Gas Revenue - Nonassoc
488901 - Epg - Wholesale Gas Revenue
488902 - Epg - Operating Rev - Gas Ops
488903 - Epg - Mtm Gas
Competitive Business
501200 - Epg - Gas-Exchange Futures/Op
501201 - Egp - Gas Swaps
501202 - Epg - Exchange Options - Gas
501203 - Fuel-Natural Gas
501204 - Natural Gas Hedging-Electric
501205 - Fuel Expense Deferral
501230 - Epg - Otc Options - Gas
501240 - Epg - Otc Options - Power
501905 - Gas Purch-OBA Settle-affil
547100 - Fuel-Ng Distr O&M
547200 - Fuel Gas Other
Fuel - Gas
501100 - Fuel - Oil
501105 - Fuel Oil - Bottom Ash
501110 - Fuel Oil Purchases
547000 - Fuel
Fuel - Oil
518000 - Nuclear Fuel Expense
518100 - Burnup/Amortization
5181NR - River Bend Fuel Burn-Rb Nonreg
518200 - Doe Spent Fuel
5182NR - River Bend Spent Fuel-Rb Nonre
518300 - Daily Lease Charges
5183NR - Daily Lease Charges - Non Reg
518400 - Other Expenses-R&P, Use & Oil
518500 - Nuclear Fuel Dry Casts Storage
5185NR - Nuclear Dry Cast Strg-RBnonreg
518600 - Fuel Exp-Decomm & Decontam
Fuel - Nuclear
501000 - Fuel
501120 - Epg - Coal Purchases
(181)
1,131,089
1,131,089
947,884
71,906
275
72,180
763
763
48,816
1,281
3,573
3,781
1,159
58,609
108
-
E-2 Supporting Schedule Page 10 of 30
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41
Schedule E-2 Supporting Schedule
Income Statement - Total Company
Partially Projected Test Year Ended
March 31, 2015
Arkansas Public Service Commission
Minimum Filing Requirements
Entergy Arkansas, Inc.
Docket No. 15-015-U
A0000 - Entergy Arkansas Inc.
Balance in Thousands
6 Mos Ended
9/30/14
Line #
512 Total Operating Revenues
513
514
515
516
517
518
519
520
521
522
523
524
525
526
527
528
529
530
531
532
533
534
535
536
537
538
539
540
541
542
543
544
545
546
547
548
549
550
551
552
553
554
555
556
557
558
559
560
561
562
Amounts may not add or tie to other
schedules due to rounding.
Total Operating Revenues
Gas purchased for resale
Fuel-related expenses
Deferred fuel - electric
Deferred fuel - gas
501300 - Gas Transportation
501301 - Fuel - Coal
501400 - Fuel - Coal - InterCo Elim
Fuel - Coal
804000 - Natural Gas City Gate Purchase
804100 - Gas Purchases
Gas purchased for resale
509000 - Allowance
509100 - NOX Emissions Allowance Exp
509101 - NOX Seasonal Allowances Exp
557001 - NOX Deferred Expense
557100 - Nuclear Reserve
Fuel-related expenses
557002 - Deferred Electric Fuel Cost
557003 - Electric Deferred Fuel
557004 - Def O/U Exp Nisco Reclass
557005 - Deferred TX capacity rider
557200 - Natural Gas Hedging
557310 - Def. Electric-Fuel Res Costs
557390 - Def Sys Agreemt Paymt/Receipts
557NR0 - Non Regulated Deferred Fuel
Deferred fuel - electric
880180 - Def Gas Cost
880200 - Natural Gas Hedging-Resale Gas
Deferred fuel - gas
Total Fuel Rel Exp, Gas Resale
Purchased Power
555000 - Epg - Purchased Power-Entergy
555001 - System Companies Purchases
555002 - System Purchases From Others
555003 - Power Purchased
555004 - Heat Rate Correction Factor
555005 - Co-Generation
555010 - Rsrc Plan Purch Pwr - Affiltd
555011 - Add'l RSRC Plan PurchPwr 2010
555015 - MISO Schedule 24 Admin
555020 - ResplanPurchase-NonAssociated
555100 - Purchase Power from EPI
555102 - Purchased Power Outside
555103 - Purchase Power Outside Retail
555104 - Accrued Purch Pwr O/S Retail
555116 - Purchases From Co-Owners
555200 - Purch Power-Entergy-Affiliates
555303 - Grand Gulf Rider Exp Deferral
555390 - System Agreement Payments
5555CA - Capacity Purchases-Affil
555900 - Capacity Deferral
555906 - Ancillary Svcs exp-affil
555908 - Station Svc Purch - affil
555ELM - Purchased Power - Affiliate
555FTS - FTR Actualization per MISO
555FTV - Mkt Value - MISO FTRs
107,465
107,573
4
61
65
(29,772)
(105,565)
(135,337)
103,854
9
84,836
169
32
244
122,513
5,163
105,552
(3,903)
-
E-2 Supporting Schedule Page 11 of 30
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41
Schedule E-2 Supporting Schedule
Income Statement - Total Company
Partially Projected Test Year Ended
March 31, 2015
Arkansas Public Service Commission
Minimum Filing Requirements
Entergy Arkansas, Inc.
Docket No. 15-015-U
A0000 - Entergy Arkansas Inc.
Balance in Thousands
6 Mos Ended
9/30/14
Line #
563 Total Operating Revenues
564
565
566
567
568
569
570
571
572
573
574
575
576
577
578
579
580
581
582
583
584
585
586
587
588
589
590
591
592
593
594
595
596
597
598
599
600
601
602
603
604
605
606
607
608
609
610
611
612
613
Amounts may not add or tie to other
schedules due to rounding.
Total Operating Revenues
557400 - MISO Misc Purchased Pwr Exp
588200 - Non-Affiliate Misc Distr Exp
588300 - Accrued Non-Affil Misc Dis Exp
Purchased Power
Nuc refueling outage expenses 517001 - Nuc Out Amort-Op, Supv, & Eng
519001 - Nuc Out Amort-Coolants & Water
520001 - Nuc Out Amort - Steam Expenses
521001 - Nuc Out Amort - Steam Other
523001 - Nuc Out Amort-Electric Expense
524001 - Nuc Out Amort-Misc Nuc Pow Exp
525001 - Nuc Out Amort - Rents
528001 - Nuc Out Amort-Maint Supv & Eng
529001 - Nuc Out Amort-Maint Of Structu
530001 - Nuc Out Amort-Maint Reator Plt
531001 - Nuc Out Amort-Maint Elec Plant
532001 - Nuc Out Amort-Maint Misc Nuc P
Nuc refueling outage expenses
Operation
107EXP - Capital Charges To Expense
121EXP - Capital Charges To Expense
154EXP - General Inventory To Expense
163EXP - Stores Ech To Expense
165EXP - Prepaid Expense
174EXP - Misc Current & Accrued Expense
184EXP - Oth Bal Sheet Chrgs To Expense
401000 - Operating Expense
40100N - Nuc Trans- Operating Expense
411800 - Gain From Dispostn Of Allownce
421102 - Gain on Sale of EPV
4212AM - Loss On Disposition Of Proprty
4265NW - New Nuclear Disallowance
4265OT - Disallowed Other Exp
426X03 - OM reclass from Otr Ded.
500000 - Oper Supervision & Engineerin
501600 - Cost Of Goods Sold
501700 - Costs-Oil&Gas Exploration
502000 - Steam Expenses
502100 - Chemicals-MATS Compliance
503000 - Steam From Other Sources
504000 - Steam Transferred - Credit
505000 - Electric Expenses
506000 - Misc Steam Power Expenses
506100 - Epg - Non Fuel O&M
507000 - Rents - Steam Power Generation
507100 - EGSI-GSG&T I/U Rent - Affiltd
517000 - Operation, Supervision & Engr
51700N - Nuc Trans- Operation, Superv &
519000 - Coolants And Water
51900N - Nuc Trans- Coolants And Water
520000 - Steam Expenses
52000N - Nuc Trans- Steam Expenses
521000 - Steam From Other Sources
50
314,665
22,040
22,040
(0)
27
2,258
3,788
1,250
826
1,751
68
12,352
3,257
18,939
-
E-2 Supporting Schedule Page 12 of 30
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41
Schedule E-2 Supporting Schedule
Income Statement - Total Company
Partially Projected Test Year Ended
March 31, 2015
Arkansas Public Service Commission
Minimum Filing Requirements
Entergy Arkansas, Inc.
Docket No. 15-015-U
A0000 - Entergy Arkansas Inc.
Balance in Thousands
6 Mos Ended
9/30/14
Line #
614 Total Operating Revenues
615
616
617
618
619
620
621
622
623
624
625
626
627
628
629
630
631
632
633
634
635
636
637
638
639
640
641
642
643
644
645
646
647
648
649
650
651
652
653
654
655
656
657
658
659
660
661
662
663
664
Amounts may not add or tie to other
schedules due to rounding.
Total Operating Revenues
52100N - Nuc Trans- Steam From Other So
522000 - Steam Transferred - Credit
52200N - Nuc Trans- Steam Transferred-C
523000 - Electric Expenses
52300N - Nuc Trans- Electric Expenses
524000 - Misc. Nuclear Power Expenses
52400N - Nuc Trans- Misc. Nuclear Power
525000 - Rents - Nuclear Generation
52500N - Nuc Trans- Rents
535000 - Operating Supervision & Engin
536000 - Water For Power
537000 - Hydraulic Expenses
538000 - Electric Expenses
539000 - Misc Hydro Power Generation
540000 - Rents - Hydraulic Power Gener
546000 - Operation Superv & Engineerin
546100 - Oper Enginering/Tech Support
548000 - Generation Expenses
548100 - Other Operating Costs
548101 - Lab Costs
548102 - Process Control Costs
548103 - Operating Supplies,Water,Waste
549000 - Misc Oth Pwr Generation Exps
549100 - Environ Permits / Testing
549101 - Misc Oper Fees / Svcs
549102 - Plant Overheads/O&M Mgmnt Fees
549103 - Variable Costs - Operations
549104 - Site Service Fee
549105 - B/U Steam Cap Chg
550000 - Rents - Other Power Generation
556000 - System Control & Load Disp.
557000 - Other Expenses
557006 - Other Expenses - Intercompany
557907 - EMA / ISO fee exp. - affiliate
557908 - Placeholder
560000 - Oper Super & Engineering
560AA0 - Alloc Of Oper Supv - Transm
561000 - Load Dispatching
561100 - Load dispatch - reliability
561200 - Load Dispatch- transm system
5612BA - LBA Schedule 24 Recoverable
561300 - Load disptch-transm serv & sch
561410 - MISO Schedule 10 Admin
561500 - Syst plan & standards devlpmnt
561600 - Transmission Service Studies
561700 - Generatn interconnectn studies
561800 - Reliability planning
5618BB - MISO Schedule BB
562000 - Station Expenses
56200N - Nuc Trans- Station Expenses
562100 - Transmission/Elect Substation
16,816
2,139
123
152
545
177
15
793
559
2,112
16
672
147
2,814
127
970
215
213
1,890
346
18
3
327
-
E-2 Supporting Schedule Page 13 of 30
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41
Schedule E-2 Supporting Schedule
Income Statement - Total Company
Partially Projected Test Year Ended
March 31, 2015
Arkansas Public Service Commission
Minimum Filing Requirements
Entergy Arkansas, Inc.
Docket No. 15-015-U
A0000 - Entergy Arkansas Inc.
Balance in Thousands
6 Mos Ended
9/30/14
Line #
665 Total Operating Revenues
666
667
668
669
670
671
672
673
674
675
676
677
678
679
680
681
682
683
684
685
686
687
688
689
690
691
692
693
694
695
696
697
698
699
700
701
702
703
704
705
706
707
708
709
710
711
712
713
714
715
Amounts may not add or tie to other
schedules due to rounding.
Total Operating Revenues
563000 - Overhead Line Expenses
564000 - Underground Line Expenses
565000 - Epg - Transmission Of Electric
565100 - Epg - Transmission Of Assoc
565200 - Transmission Costs-Spot Sales
565300 - Transmission Charges - Ap&L
565399 - Transmission Equalization
565400 - Transmission Elec. By Others
565FFR - FFR Transm Expense
565NR0 - Transm Elec. By Others Nonreg
566000 - Misc. Transmission Expenses
566010 - Misc Trans-Ouachita Upgrades
566100 - Brokers Fee Gas
566101 - Brokers Fee
566AA0 - Alloc Of Misc Oper - Transm
567000 - Rents - Transmission System
567100 - Rent - Affiliated
575100 - Regional Energy Mkts-Oper Supv
575200 - Day-Ahead and Real-Tm Mkt Adm
575201 - DayAhead and RealTm Mkts WPP
575700 - MISO Market Admin Charges
580000 - Operation Supervision&Enginee
580AA0 - Alloc Of Oper Supv - Distr
581000 - Load Dispatching
582000 - Station Expenses
583000 - Overhead Line Expenses
584000 - Underground Line Exps
585000 - Street Light & Signal System
585199 - Bad Account - Conversion Mappi
586000 - Meter Expenses
587000 - Customer Installation Expense
588000 - Misc Distribution Expense
588100 - Affiliate Misc Distr Expense
588AA0 - Alloc Of Misc Oper - Distr
589000 - Rents - Distribution System
850000 - Operation Supervision & Eng
851000 - System Control & Load Dispatch
852000 - Communication System Expense
853000 - Compressor Station Labor&Exp
855000 - Other Fuel & Power
856000 - Mains Expenses
857000 - Measurng & Regulatng Statn Exp
859000 - Other Expenses-Gas Transm
860000 - Rents
861000 - Maint Supervision & Engineerin
867000 - Maint Of Other Equipment
870000 - Operation Supervision & Eng
870AA0 - Alloc Of Oper Supv - Gas Distr
871000 - Distribution Load Dispatching
874000 - Mains & Services Expense
875000 - Measuring & Reg. Station Exp.
468
3,460
289
2,330
1,613
86
1
1,832
5,566
333
211
1,037
909
55
2,305
590
1,635
1,094
-
E-2 Supporting Schedule Page 14 of 30
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41
Schedule E-2 Supporting Schedule
Income Statement - Total Company
Partially Projected Test Year Ended
March 31, 2015
Arkansas Public Service Commission
Minimum Filing Requirements
Entergy Arkansas, Inc.
Docket No. 15-015-U
A0000 - Entergy Arkansas Inc.
Balance in Thousands
6 Mos Ended
9/30/14
Line #
716 Total Operating Revenues
717
718
719
720
721
722
723
724
725
726
727
728
729
730
731
732
733
734
735
736
737
738
739
740
741
742
743
744
745
746
747
748
749
750
751
752
753
754
755
756
757
758
759
760
761
762
763
764
765
766
Amounts may not add or tie to other
schedules due to rounding.
Total Operating Revenues
876000 - Measur & Reg. Station Exp-Indu
877000 - Meas &Reg Sta Exp-Cty Gate Chk
878000 - Meter & House Regulator Expens
879000 - Customer Installations Expense
880000 - Other Expenses
881000 - Rents - Oper of the Distr Sys
901000 - Supervision
902000 - Meter Reading Expenses
903000 - Cust Records & Coll Expenses
903001 - Customer Records
903002 - Collection Expense
903291 - PMRF A54 Allocation
9032JJ - Exp-Bill to 107600
904000 - Uncollectible Accounts
904001 - Uncollect Acct Elect-Write Off
904002 - Uncollect Acct Gas-Write Off
904003 - Uncollect Acct Electr-Reinstat
904004 - Uncollect Acct Gas-Reinstate
904005 - Cancellation Of Debt Income
905000 - Misc Customer Accounts Exp
907000 - Supervision
907AA0 - Alloc Of Supv - Cust Serv
908000 - Customer Assistance Expenses
908100 - Customer assistance over/under
909000 - Information & Instruct Adv Ex
910000 - Misc Cust Ser &Information Ex
91000N - Nuc Trns-Misc Cust Serv & Info
910AA0 - Alloc Of Misc Cust Serv Exp
911000 - Supervision
912000 - Demon. & Selling Exp.
913000 - Advertising Expense
913001 - Amortize Accrued Market Cost
916000 - Miscellaneous Sales Expenses
920000 - Adm & General Salaries
92000N - Nuc Trans- Adm & General Salar
920299 - Incentive Compensation Loader
921000 - Office Supplies And Expenses
92100N - Nuc Trans- Office Supplies And
921010 - Fiber Optics Equalization
921100 - Taxable Employee Expenses
921U24 - Interdepartmental Expense
921U25 - Interdepartmental Expense
921U26 - Interdepartmental Expense
921U27 - Interdepartmental Expense
921U28 - Interdepartmental Expense
922000 - Adm. Expense Transferred - Cr
922300 - Billing To Eei Divisions
923000 - Outside Services Employed
923001 - Non-reg nuclear fuel legal fee
92300N - Nuc Trans-Outside Services Emp
923100 - Outside Services/Esi-Non-Epg
220
3,381
6,874
4,897
513
3,312
19
545
27,576
8,232
335
597
7
2
49
228
19,472
2,064
446
(2,157)
12,445
-
E-2 Supporting Schedule Page 15 of 30
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41
Schedule E-2 Supporting Schedule
Income Statement - Total Company
Partially Projected Test Year Ended
March 31, 2015
Arkansas Public Service Commission
Minimum Filing Requirements
Entergy Arkansas, Inc.
Docket No. 15-015-U
A0000 - Entergy Arkansas Inc.
Balance in Thousands
6 Mos Ended
9/30/14
Line #
767 Total Operating Revenues
768
769
770
771
772
773
774
775
776
777
778
779
780
781
782
783
784
785
786
787
788
789
790
791
792
793
794
795
796
797
798
799
800
801
802
803
804
805
806
807
808
809
810
811
812
813
814
815
816
817
Amounts may not add or tie to other
schedules due to rounding.
Total Operating Revenues
923107 - Outside Services/Esi
923250 - ENOI Bankruptcy External Cost
923300 - Admin Fees - Wind JV
924000 - Property Insurance Expense
924004 - Prov. For Property Insurance
924005 - Environmental Reserve Accrual
924006 - Nuclr Insur Adj & Distribtns
92400N - Nuc Trans- Property Insurance
925000 - Injuries & Damages Expense
92500N - Nuc Trans- Injuries & Damages
926000 - Employee Pension & Benefits
92600N - Nuc Trans- Employee Pension &
926299 - Employee Benefits Respon View
928000 - Regulatory Commission Expense
92800N - Nuc Trans-Regulatory Commissio
928100 - Regulatory Comm Exp-Over/Under
929000 - Duplicate Charges-Credit
93000N - Nuc Trans - Misc General Expen
930100 - General Advertising Expenses
930200 - Miscellaneous General Expense
930201 - Active Development Expenses
930202 - Ip2-Amort Def Rev
930203 - Vy-Amort Def Rev
930204 - Joint Ownership Costs
930205 - Exp-Bill to 107611
930206 - Exp-Bill to 10761R
930207 - Exp-Bill to 10761S
930208 - Exp-Bill to 107EXP
930209 - Exp-Bill to 107NR0
93020A - Exp-Bill to 184A63
93020B - Exp-Bill to 184A64
93020C - Exp-Bill to 184A65
93020D - Exp-Bill to 184A66
93020E - Exp-Bill to 184A67
93020F - Exp-Bill to 184A68
93020G - Exp-Bill to 184A69
93020H - Exp-Bill to 184A70
93020I - Exp-Bill to 184A71
93020J - Exp-Bill to 184A72
93020K - Exp-Bill to 184A73
93020L - Exp-Bill to 184A74
93020M - Exp-Bill to 184A75
93020N - Nuc Trans- Misc General Expens
93020P - Exp-Bill to 184A77
93020Q - Exp-Bill to 184A78
93020R - Exp-Bill to 184A79
93020S - Exp-Bill to 184A80
93020T - Exp-Bill to 184EXP
93020U - Exp-Bill to 186080
93020V - Exp-Bill to 186800
93020W - Exp-Bill to 186BIL
12,774
816
2,325
33,323
2,296
(10)
24
377
0
-
E-2 Supporting Schedule Page 16 of 30
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41
Schedule E-2 Supporting Schedule
Income Statement - Total Company
Partially Projected Test Year Ended
March 31, 2015
Arkansas Public Service Commission
Minimum Filing Requirements
Entergy Arkansas, Inc.
Docket No. 15-015-U
A0000 - Entergy Arkansas Inc.
Balance in Thousands
6 Mos Ended
9/30/14
Line #
818 Total Operating Revenues
819
820
821
822
823
824
825
826
827
828
829
830
831
832
833
834
835
836
837
838
839
840
841
842
843
844
845
846
847
848
849
850
851
852
853
854
855
856
857
858
859
860
861
862
863
864
865
866
867
868
Amounts may not add or tie to other
schedules due to rounding.
Total Operating Revenues
93020X - Exp-Bill to 228400
93020Y - Exp-Bill to 232704
93020Z - Exp-Bill to 260001
930210 - Director's Fees And Expenses
930211 - Exp-Bill to 108220
930212 - Exp-Bill to 108230
930213 - Exp-Bill to 108240
930214 - Exp-Bill to 108250
930215 - Exp-Bill to 10830N
930216 - Exp-Bill to 10840N
930217 - Exp-Bill to 10850N
930218 - Exp-Bill to 118001
930219 - Exp-Bill to 119220
930220 - Affiliate service fee expense
930221 - Exp-Bill to 121700
930222 - Exp-Bill to 121EXP
930223 - Exp-Bill to 121WIP
930224 - Exp-Bill to 152000
930225 - Exp-Bill to 154EXP
930226 - Exp-Bill to 163000
930227 - Exp-Bill to 16300N
930228 - Exp-Bill to 163921
930229 - Exp-Bill to 163963
930230 - Exp-Bill to 163EXP
930231 - Exp-Bill to 165EXP
930232 - Exp-Bill to 174101
930233 - Exp-Bill to 174EXP
930234 - Exp-Bill to 181000
930235 - Exp-Bill to 183000
930236 - Exp-Bill to 184000
930237 - Exp-Bill to 184001
930238 - Exp-Bill to 174104
930239 - Exp-Bill to 174200
930240 - Exp-Bill to 184A03
930241 - Exp-Bill to 184A04
930242 - Exp-Bill to 184A05
930243 - Exp-Bill to 184A06
930244 - Exp-Bill to 184A07
930245 - Exp-Bill to 184A08
930246 - Exp-Bill to 184A09
930247 - Exp-Bill to 184A10
930248 - Exp-Bill to 184A11
930249 - Exp-Bill to 184A12
930250 - Exp-Bill to 184A13
930251 - Exp-Bill to 184A14
930252 - Exp-Bill to 184A15
930253 - Exp-Bill to 184A16
930254 - Exp-Bill to 184A17
930255 - Exp-Bill to 184A18
930256 - Exp-Bill to 184A19
930257 - Exp-Bill to 184A20
74
-
E-2 Supporting Schedule Page 17 of 30
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41
Schedule E-2 Supporting Schedule
Income Statement - Total Company
Partially Projected Test Year Ended
March 31, 2015
Arkansas Public Service Commission
Minimum Filing Requirements
Entergy Arkansas, Inc.
Docket No. 15-015-U
A0000 - Entergy Arkansas Inc.
Balance in Thousands
6 Mos Ended
9/30/14
Line #
869 Total Operating Revenues
870
871
872
873
874
875
876
877
878
879
880
881
882
883
884
885
886
887
888
889
890
891
892
893
894
895
896
897
898
899
900
901
902
903
904
905
906
907
908
909
910
911
912
913
914
915
916
917
918
919
Amounts may not add or tie to other
schedules due to rounding.
Total Operating Revenues
930258 - Exp-Bill to 184A21
930259 - Exp-Bill to 184A22
930260 - Exp-Bill to 184A23
930261 - Exp-Bill to 184A24
930262 - Exp-Bill to 184A25
930263 - Exp-Bill to 184A26
930264 - Exp-Bill to 184A27
930265 - Exp-Bill to 184A28
930266 - Exp-Bill to 184A29
930267 - Exp-Bill to 184A30
930268 - Exp-Bill to 184A31
930269 - Exp-Bill to 184A32
930270 - Exp-Bill to 184A33
930271 - Exp-Bill to 184A34
930272 - Exp-Bill to 184A35
930273 - Exp-Bill to 184A36
930274 - Exp-Bill to 184A37
930275 - Exp-Bill to 184A38
930276 - Exp-Bill to 184A39
930277 - Exp-Bill to 184A40
930278 - Exp-Bill to 184A41
930279 - Exp-Bill to 184A42
930280 - Exp-Bill to 184A43
930281 - Exp-Bill to 184A44
930282 - Exp-Bill to 184A45
930283 - Exp-Bill to 184A46
930284 - Exp-Bill to 184A47
930285 - Exp-Bill to 184A48
930286 - Exp-Bill to 184A49
930287 - Exp-Bill to 184A50
930288 - Exp-Bill to 184A51
930289 - Exp-Bill to 184A52
930290 - Exp-Bill to 184A53
930291 - Exp-Bill to 184A54
930292 - Exp-Bill to 184A55
930293 - Exp-Bill to 184A56
930294 - Exp-Bill to 184A57
930295 - Exp-Bill to 184A58
930296 - Exp-Bill to 184A59
930297 - Exp-Bill to 184A60
930298 - Exp-Bill to 184A61
930299 - Exp-Bill to 184A62
9302AA - Exp-Bill to 107000
9302BB - Exp-Bill to 107120
9302BR - ENOI Bankruptcy Internal Costs
9302CC - Exp-Bill to 107500
9302DD - Exp-Bill to 184A76
9302EE - Exp-Bill to 10820N
9302FF - Exp-Bill to 107000
9302GG - Exp-Bill to 107120
9302HH - Exp-Bill to 107500
-
E-2 Supporting Schedule Page 18 of 30
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41
Schedule E-2 Supporting Schedule
Income Statement - Total Company
Partially Projected Test Year Ended
March 31, 2015
Arkansas Public Service Commission
Minimum Filing Requirements
Entergy Arkansas, Inc.
Docket No. 15-015-U
A0000 - Entergy Arkansas Inc.
Balance in Thousands
6 Mos Ended
9/30/14
Line #
920 Total Operating Revenues
921
922
923
924
925
926
927
928
929
930
931
932
933
934
935
936
937
938
939
940
941
942
943
944
945
946
947
948
949
950
951
952
953
954
955
956
957
958
959
960
961
962
963
964
965
966
967
968
969
970
Amounts may not add or tie to other
schedules due to rounding.
Total Operating Revenues
Maintenance
9302JJ - Exp-Bill to 107600
9302JV - Expense for B.S. Reclass
9302KK - Exp-Bill to 10820N
931000 - Rents-Cust Accts,Serv,Sales,GA
93100N - Nuc Trans- Rents
Operation
402000 - Maintenance Expense
40200N - Nuc Trans- Maintenance Expense
448000 - Interdepartmental Sales
484000 - Interdepartmental Gas Sales
510000 - Maintenance Supr & Engineerin
511000 - Maintenance Of Structures
512000 - Maintenance Of Boiler Plant
513000 - Maintenance Of Electric Plant
514000 - Maintenance Of Misc Steam Plt
528000 - Maint Supervision & Engr
52800N - Nuc Trans- Maint Supervision &
529000 - Maintenance Of Structures
52900N - Nuc Trans-Maintenance Of Struc
530000 - Maint Of Reactor Plant Equip
53000N - Nuc Trans-Maint Reactor Plant
531000 - Maintenance Of Electric Plant
53100N - Nuc Trans- Maint Of Electric P
532000 - Maint Of Misc Nuclear Plant
53200N - Nuc Trans- Maint Misc Nuclear
532AA0 - Alloc Of Misc Maint - Nuclear
541000 - Maintenance Supervision & Eng
542000 - Maintenance Of Structures
543000 - Maint Of Dams, Reservoirs & W
544000 - Maint Of Electric Plt
545000 - Maint Of Misc Hydraulic Plt
551000 - Maint Supv & Engineering
552000 - Maintenance Of Structures
553000 - Maint-Gener & Elec Equipment
553100 - Routine Maint - Labor
553101 - Routine Maint - Materials
553102 - Routine Maint - Contract
553103 - Offsite Maint Svcs
553104 - Major Maint - Labor
553105 - Major Maint - Materials
553106 - Major Maint - Contract
554000 - Maint-Misc Other Pwr Gen Plt
568000 - Maint. Supervision & Engineer
568AA0 - Alloc Of Maint Supv - Transm
569000 - Maintenance Of Structures
569100 - Maint Transm Computer&Telecom
569200 - Maint of transm computer softw
569300 - Maint of transm telecom equip
570000 - Maint. Of Station Equipment
57000N - Nuc Trans- Maint Of Station Eq
571000 - Maint Of Overhead Lines
2,390
242,962
432
372
5,908
1,691
355
11,419
174
6,351
4,871
10,988
3
33
287
128
71
344
158
11,493
198
2,581
108
10
1,372
3,162
E-2 Supporting Schedule Page 19 of 30
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41
Schedule E-2 Supporting Schedule
Income Statement - Total Company
Partially Projected Test Year Ended
March 31, 2015
Arkansas Public Service Commission
Minimum Filing Requirements
Entergy Arkansas, Inc.
Docket No. 15-015-U
A0000 - Entergy Arkansas Inc.
Balance in Thousands
6 Mos Ended
9/30/14
Line #
971 Total Operating Revenues
972
973
974
975
976
977
978
979
980
981
982
983
984
985
986
987
988
989
990
991
992
993
994
995
996
997
998
999
1000
1001
1002
1003
1004
1005
1006
1007
1008
1009
1010
1011
1012
1013
1014
1015
1016
1017
1018
1019
1020
1021
Amounts may not add or tie to other
schedules due to rounding.
Total Operating Revenues
Total Other Oper & Maint
Decommissioning
572000 - Maint. Of Underground Lines
573000 - Maint Misc Transmission Plant
576200 - Maint of Computer Hardware
576201 - Maint of Computer Hardware WPP
576300 - Maint of Computer Software
576301 - Maint of Computer Software WPP
590000 - Maint. Supervision & Engineer
590AA0 - Alloc Of Maint Supv - Distr
591000 - Maintenance Of Structures
591AA0 - Alloc Of Maint Struct - Distr
592000 - Maint. Of Station Equipment
593000 - Maintenance Of Overhead Lines
594000 - Maint Underground Lines
595000 - Maint. Of Line Transformers
596000 - Maint. St. Lght. & Sig. Syst.
596100 - Maint-Non-Roadwy Securty Lgtng
597000 - Maintenance Of Meters
598000 - Maint. Misc. Distribution Plt
865000 - Mnt Of Measurng & Reg Sta Equp
866000 - Maint Of Communication Equip
885000 - Maint Supervision & Engineerin
886000 - Maint. Of Structures & Improv
887000 - Maint. Of Mains
889000 - Mnt Of Meas&Reg Sta Equip-Genl
890000 - Mnt Of Meas& Reg.Sta.Equip-Ind
891000 - Mnt Of Meas&Reg Sta.Eqp-Cty Ga
892000 - Maint. Of Services
893000 - Mnt Of Metrs & House Regulatrs
894000 - Maint. Of Other Equipment
932000 - Maint Of Gas General Plant
935000 - Maintenance Of General Plant
Maintenance
403050 - River Bend Decom Exp-La Rtl
403060 - River Bend Decom Exp-Ferc
403070 - River Bend Decom Exp-Tx Rtl
403080 - River Bend Decom Exp-Steam
403902 - Decommissioning Expense
403903 - Decommissng Expense-Nqf
411105 - Accretion Expense - Aro
411106 - Accretion exp.-rate recov amt.
411107 - Accretion Exp-ARO Asset-Fossil
411108 - Accretion Exp-ARO Asset-Hydro
411109 - Accret Exp-ARO Asset-Other Gen
411601 - Gains on Settlement of ARO
Decommissioning
Taxes other than income taxes 408100 - Sales / Use Tax
408102 - Fo-Franchise Taxes
408103 - Fo-Other Taxes
408104 - Gas-Franchise Taxes
408105 - Taxes Other Than Inc-Util Op
56
1,729
520
1,755
15,995
1,022
37
548
555
73
639
1,123
86,564
329,526
23,411
246
2
8
23,667
-
E-2 Supporting Schedule Page 20 of 30
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41
Schedule E-2 Supporting Schedule
Income Statement - Total Company
Partially Projected Test Year Ended
March 31, 2015
Arkansas Public Service Commission
Minimum Filing Requirements
Entergy Arkansas, Inc.
Docket No. 15-015-U
A0000 - Entergy Arkansas Inc.
Balance in Thousands
6 Mos Ended
9/30/14
Line #
1022 Total Operating Revenues
1023
1024
1025
1026
1027
1028
1029
1030
1031
1032
1033
1034
1035
1036
1037
1038
1039
1040
1041
1042
1043
1044
1045
1046
1047
1048
1049
1050
1051
1052
1053
1054
1055
1056
1057
1058
1059
1060
1061
1062
1063
1064
1065
1066
1067
1068
1069
1070
1071
1072
Amounts may not add or tie to other
schedules due to rounding.
Total Operating Revenues
40810N - Nuc Trans- Tax Oth Than Inc-Ut
408110 - Employment Taxes
408122 - Excise Tax - State
408123 - Excise Tax - Federal
408131 - Environmental Tax
408133 - Taxs Othr Than Income Taxs-Esi
408134 - Esi Tx Oth Thn Inc Tx-Fuel Oil
408135 - Esi Tx Oth Thn Inc Tx-Oil & Gs
408142 - Ad Valorem
408143 - Ad Valorem - Ms
408144 - Ad Valorem - Ar
408146 - Ad Valorem Tax-Sale/Leaseback
408152 - Franchise Tax - State
408154 - Franchise Tax - Local
408155 - Franchise Tax - Ms
408156 - Franchise Tax - Arkansas
408157 - Franchise Tax - Missouri
408158 - Franchise Tax - Louisiana
408162 - Use Tax
408163 - Street Rentals Tax
408164 - Gross Receipts & Sales Tax
408165 - City Occupation Tax
408166 - Privilege Tax
408167 - Gas Safety & Odorization Fee
408170 - Regulatory Tax
408172 - Regulatory Commission - State
408173 - Regulatory Commission - Local
408174 - Inspection & Supervision Fee
408180 - Sales & Use Tax
408198 - Payroll Tax Loading - Credit
408199 - Payroll Tax Loading
4081F1 - Severance Tax Ms. Gas
4081F2 - Severance Tax Ms. Condens.
4081F3 - Severance Tax Ms. Crude
4081F4 - Sales Tax Admin Overhead
4081F6 - Sales Tax Lease-Use Gas
4081F8 - Property Tax-Ad Valorem
4081F9 - Fuel Oil-Property Taxes
4265TX - Disalow PR Tx
Taxes other than income taxes
Total Oper & Maint
Depreciation and Amortization 403000 - Depreciation Expense
403001 - Depreciation Exp - Rb Abeyed
403002 - Dep Exp Elec Cwip In Rate Bse
40300N - Nuc Trans- Depreciation Expens
403010 - Amortization Of License
403066 - Amort Big Cajun Tx Rte Depr
403090 - Riverbend Afudc Gross Up
4030AM - Depreciation Expense
4030CJ - Depr Exp Cajun Settlement
4030GI - Depr Exp Contra PIS LA Securit
6,531
17
2
17,401
580
21,071
170
4
11
0
1,707
0
112
47,606
841,358
105,072
-
E-2 Supporting Schedule Page 21 of 30
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41
Schedule E-2 Supporting Schedule
Income Statement - Total Company
Partially Projected Test Year Ended
March 31, 2015
Arkansas Public Service Commission
Minimum Filing Requirements
Entergy Arkansas, Inc.
Docket No. 15-015-U
A0000 - Entergy Arkansas Inc.
Balance in Thousands
6 Mos Ended
9/30/14
Line #
1073 Total Operating Revenues
1074
1075
1076
1077
1078
1079
1080
1081
1082
1083
1084
1085
1086
1087
1088
1089
1090
1091
1092
1093
1094
1095
1096
1097
1098
1099
1100
1101
1102
1103
1104
1105
1106
1107
1108
1109
1110
1111
1112
1113
1114
1115
1116
1117
1118
1119
1120
1121
1122
1123
Amounts may not add or tie to other
schedules due to rounding.
Total Operating Revenues
4030IE - Depr Exp Contra PIS Isaac
4030IS - Depr Exp Contra PIS EAI Securi
4030LA - Depr Exp Contra PIS LA Securit
4030TA - Depr Exp Contra PIS TX Secur
4030TR - Depr Exp Contra TX Rita Secur
403100 - Depreciation Exp-Serv Co Alloc
403110 - Depr Expense - Aro Assets
403115 - Dep Exp-Remov-Fos Steam Contra
403116 - Deprec Exp ARO Asset-Fossil
403117 - Dep Exp-Removal-Hydro Contra
403118 - Deprec Exp-ARO Asset-Hydro
403119 - Dep Exp-Remove-Oth Gen Contra
403120 - Deprec Exp-ARO Asset-Other Gen
4031AM - Deprec Exp billed from Serv Co
403200 - Depreciation Rev On Slb Lease
403300 - Depr Exp for Jack Data Ctr Bld
403601 - Gas-Dep-Off Furn-Fixt
403603 - Fo-Dep-Off Furn-Fixt
403605 - Dep-Fo Stor-Handling
403606 - Amort-Gas Exploration
403611 - Amort-Leashold Improve
403614 - Amort-Long Range Focont
403700 - Depreciation & Amortizatn -Esi
403904 - Depreciation Exp- Regulatory
404000 - Amort Limited Term Elec Plant
40400N - Nuc Trans-Amort Ltd Term Elec
4040AM - Amort Limited Term Electrc Plt
404100 - Amort-Limtd Term-Serv Co Alloc
4041AM - Amort Exp billed from Serv Co
404200 - Amortization Of Slb Lease Imp
404300 - Amort Limited Term Gas Plant
4043AM - Amort Plt Under Sale-Lease-Bac
406000 - Amort Of Elec Plant Acq Adj
407000 - Amortization Of Property Loss
407312 - Ises Synchronization Adjustmnt
407318 - Reg Debit Ferc Settle 1994
407335 - Gain Neches Unit 7
407346 - Amort Reg Asset-Rb Afudc Gross
407435 - Power Plt Inv-La Ret
407U01 - Amrt Rb#2 Cancl Loss-Tx Retail
407U02 - Amrt Rb#2 Cancl Loss-La Retail
4265AM - Disallowed Amort Exp
4265DP - Disallowed Depr Exp
Depreciation and Amortization
Other regulatory charges - net 407036 - Amort Contra-Afudc-Tx Retail
407037 - Amort Contra-Afudc-La Retail
407300 - Accel Amort Fas 109
407301 - Amort Enoi Least Cst Plng Ridr
407302 - Accelerated Amorti-Depr-Eai
407303 - Gg1 Costs-Over/Under Recvry-A
407304 - Def Ret On Exc Cap-Ar Gg1 Sett
(502)
1,090
(83)
3
(1)
0
(0)
0
4,709
8,336
9
507
(90)
(138)
118,912
-
E-2 Supporting Schedule Page 22 of 30
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41
Schedule E-2 Supporting Schedule
Income Statement - Total Company
Partially Projected Test Year Ended
March 31, 2015
Arkansas Public Service Commission
Minimum Filing Requirements
Entergy Arkansas, Inc.
Docket No. 15-015-U
A0000 - Entergy Arkansas Inc.
Balance in Thousands
6 Mos Ended
9/30/14
Line #
1124 Total Operating Revenues
1125
1126
1127
1128
1129
1130
1131
1132
1133
1134
1135
1136
1137
1138
1139
1140
1141
1142
1143
1144
1145
1146
1147
1148
1149
1150
1151
1152
1153
1154
1155
1156
1157
1158
1159
1160
1161
1162
1163
1164
1165
1166
1167
1168
1169
1170
1171
1172
1173
1174
Amounts may not add or tie to other
schedules due to rounding.
Total Operating Revenues
407305 - Current Share-Ar Gg1 Set
407306 - Accelerated Amorti - Depr.-Emi
407307 - Accelerated Amorti-Def Tax-Emi
407308 - Accelerated Amorti-Def Tax-Eai
407309 - Deferred Waterford 3 Expenses
407310 - Grand Gulf 1 Rate Deferral
407311 - Gg1 Phase - In Recovery
407313 - Deferred Grand Gulf 1 Expense
407314 - Gas Rate Phase - In Deferral
407315 - Gg1 Settlement
407316 - Gg1 Under/Over Collection
407317 - Mp&L Ice Storm Amaortization
407319 - Pmr Rider Overunderrecoveryemi
407320 - Amortization Of Sfas 106 Defe
407325 - Reg DR-ARO-Asbestos Removal
407328 - Period One Alj
407329 - Wf3 Property Tax Regulatory De
407331 - Rb Def Oper Costs-Tx Ret
407332 - Y2K Amortization
407333 - Rb Def Revenue Req-La Ret
407334 - Rb Def Oper Costs-La Ret
407336 - Amort Enoi Distr O&M Expenses
407338 - Spindletop Cap Cost La Amort
407339 - Sgr Spur Cap Cst La Amort (LG)
407340 - Sgr Spur Recovery (G4)
407341 - Amortiz Of The Neches 7 Gain
407342 - Reg DR - Fed. Lit. Consult Fee
407343 - Reg Debit-Energy Efficiency
407344 - Reg Debit-EAI 30-Year Retail
407345 - Reg DR-Extraord Storm Restor
407347 - River Bend Afudc -La Retail
407348 - Regulatory Debits
407349 - RegulatoryDebits -186RES amort
407350 - Regulatory Debits - Aro
407351 - Reg. Debit-Amort Sec ADIT Ben
407352 - Reg DR -Storm Securitization
407353 - Reg Debit - TTC amortization
407354 - Reg Debit - Rate Case Costs
407355 - Reg Debit - Storm Cost Offset
407356 - Reg Debit - Act 310
407357 - Reg Debit - EAI Study
407358 - Reg Debit-Ike Generation Costs
407360 - Reg Credit-LG Over/Under
407361 - Reg Debit - Little Gypsy Amort
407362 - Reg Dr Guar/Cont Svgs-K/R Sec
407363 - Regulatory Debits-MISO Rider
407364 - Reg Dr - EAI Storm Interest
407365 - Reg Debit-RB3/GG3 Amtz
407399 - Seri Refund Credit
4073T7 - AMORT ETI RATE CASE 2007
407400 - Gg1 Deferral True-Up Ap&L
263
1,271
7,238
1,696
47
-
E-2 Supporting Schedule Page 23 of 30
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41
Schedule E-2 Supporting Schedule
Income Statement - Total Company
Partially Projected Test Year Ended
March 31, 2015
Arkansas Public Service Commission
Minimum Filing Requirements
Entergy Arkansas, Inc.
Docket No. 15-015-U
A0000 - Entergy Arkansas Inc.
Balance in Thousands
6 Mos Ended
9/30/14
Line #
1175 Total Operating Revenues
1176
1177
1178
1179
1180
1181
1182
1183
1184
1185
1186
1187
1188
1189
1190
1191
1192
1193
1194
1195
1196
1197
1198
1199
1200 Operating Income (Loss)
1201
1202
1203
1204 Total Other Income
1205
1206
1207
1208
1209
1210
1211
1212
1213
1214
1215
1216
1217
1218
1219
1220
1221
1222
1223
1224
1225
Amounts may not add or tie to other
schedules due to rounding.
Total Operating Revenues
407401 - Deferred Least Cost Planning
407402 - Gg1 Rate Defrl Pln (Rider Rdp)
407403 - Regulatory Credits
407404 - Regulatory Credits - Capacity
407405 - Capacity Acquisition Rider Def
407406 - Reg Credit EMI GGART Amort
407407 - Reg Credit EMI GGART Taxes
407410 - Regulatory Credit - Aro
407411 - Reg Credit - WF3 SaleLeaseback
407425 - Reg Credit-ARO-Asbestos Remov
407429 - Wf3 Property Tax Regulatory
407432 - Y2K Deferral
407436 - Tx Retail Power Plnt Inventory
407437 - Distribution Maint Deferral
407438 - Spindletop Cap Cost La Deferal
407439 - Sgr Spur Cap Cost La Deferral
407440 - Sgr Amort Of Spur Recovery
407448 - Regulatory Credit Vidalia Tax
407462 - Reg Cr Guar/Cont Svgs-K/R Sec
407463 - Regulatory Credit-MISO Rider
Other regulatory charges - net
Total Deprec & Amort
Total Operating Expenses
More & hidden
Total Operating Expenses
Operating Income (Loss)
Operating Income (Loss)
More & hidden
Operating Income (Loss)
Total Other Income
Allow eq funds used dur const 419100 - Afudc - Other Funds
41910N - Nuc Trans- Afudc - Other Funds
419120 - Afudc-Gross Oth Funds
419130 - Afudc-Gross Oth Funds-Bk Only
4265AE - AFDC Eqty Cntr
Allow eq funds used dur const
Interest and Dividend Income 419000 - Interest & Dividend Income
419001 - Decomm. Trust Interest - Debit
419002 - Gg1 Rate Defrl Pln (Rider Rdp)
419003 - Decomm - realized gains/losses
419004 - Decomm - Trust Earnings
41900N - Nuc Trans- Interest & Dividend
419010 - Dividend Income
419011 - Affiliated Interest Income
419012 - Interest Income - Sfi
419017 - Int Income Nopsi Gas Phase-In
419018 - Int Income W-3 Decomm Trust
419019 - Interest Income - Esi
419024 - Interest Income-So Gulf Railwy
419025 - Interest Income-Gsgtt
419026 - Interco Int Inc-Unrelated
(2,000)
(16,829)
(175)
(3,898)
(12,387)
106,526
947,884
947,884
183,206
183,206
183,206
19,486
(5,194)
1,718
3,476
(7,219)
(9,186)
(2)
-
E-2 Supporting Schedule Page 24 of 30
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41
Schedule E-2 Supporting Schedule
Income Statement - Total Company
Partially Projected Test Year Ended
March 31, 2015
Arkansas Public Service Commission
Minimum Filing Requirements
Entergy Arkansas, Inc.
Docket No. 15-015-U
A0000 - Entergy Arkansas Inc.
Balance in Thousands
6 Mos Ended
9/30/14
Line #
1226 Total Operating Revenues
1227
1228
1229
1230
1231
1232
1233
1234
1235
1236
1237
1238
1239
1240
1241
1242
1243
1244
1245
1246
1247
1248
1249
1250
1251
1252
1253
1254
1255
1256
1257
1258
1259
1260
1261
1262
1263
1264
1265
1266
1267
1268
1269
1270
1271
1272
1273
1274
1275
1276
Amounts may not add or tie to other
schedules due to rounding.
Total Operating Revenues
Eq in earn of uncons eq affil
Plant Acquistion Adjustment
Gain (loss) on sale
419027 - Interco Int Inc-Related
419205 - Interest-Decomm Trust - Qf
419206 - Interest-Decomm Trust - Nqf
419207 - Qf Decomm Trust Interest-Debit
419208 - Non-Qf Decom Trst Intrst-Debit
419209 - Interest Inc-Decom Accretion
419210 - Gty Fees Income-Interco
419211 - Int Inc - Ip2 Factoring
419212 - Int Inc - By Factoring
419300 - Dividend Income From Subsidiar
419301 - Dividend Income From Euk Ltd
419302 - Interest Income
419303 - Interest Inc-Collateral Dep
419313 - Int. inc.-prefund. ins. escrow
419DAA - Interest Income - DAA
431002 - Decommissioning Trust
Interest and Dividend Income
418010 - Erpc Earnings
418011 - Rpe Earnings
418012 - Rpe Reserve For Earnings
418013 - Equity Earning in ENNEB (7T)
418030 - Epl Earnings
418040 - Ephil1 Earnings
418041 - Eprsc Earnings
418045 - Epcbahl Earnings
418047 - Epci Earnings
418048 - Epcsa Earnings
418050 - Generandes Earnings
418055 - Epsa Earnings
418060 - Ieq Earnings (Inversiones Elec
418061 - Rs Cogen Earnings
418104 - Equity in earnings-Arklahoma
418146 - Equity In Earnings Of Ek, Lp
418164 - Equity in Earnings-Top Deer
418168 - Equity in earnings - ENOI
4181U1 - Eqty In Earngs Of Subs Varibus
4181U3 - Eqty In Earngs Of Sub Prudenti
4181U5 - Eqty In Earnings S.Gulf Railwy
4181U6 - Equty In Earnings Of Sub Gsg&T
418344 - Crete Earnings
418345 - Crete-Earnings Cthl(Crete Turb
Eq in earn of uncons eq affil
425000 - Miscellaneous Amortization
Plant Acquistion Adjustment
421101 - Miscellaneous Inc Or Loss Spec
4211CP - Gain On Disposition Of Citipow
4211ED - Gain On Disposition Of Edesur
4211GS - Gain or Loss Gulf South
4211KT - Gain or Loss Koch Trading
4211LD - Gain On Disposition Of London
Gain (loss) on sale
16,407
-
E-2 Supporting Schedule Page 25 of 30
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41
Schedule E-2 Supporting Schedule
Income Statement - Total Company
Partially Projected Test Year Ended
March 31, 2015
Arkansas Public Service Commission
Minimum Filing Requirements
Entergy Arkansas, Inc.
Docket No. 15-015-U
A0000 - Entergy Arkansas Inc.
Balance in Thousands
6 Mos Ended
9/30/14
Line #
1277 Total Operating Revenues
1278
1279
1280
1281
1282 Income Before Interest & Taxes
1283
1284
1285
1286 Total Interest and Oth Charges
1287
1288
1289
1290
1291
1292
1293
1294
1295
1296
1297
1298
1299
1300
1301
1302
1303
1304
1305
1306
1307
1308
1309
1310
1311
1312
1313
1314
1315
1316
1317
1318
1319
1320
1321
1322
1323
1324
1325
1326
1327
Amounts may not add or tie to other
schedules due to rounding.
Total Operating
Misc - net Revenues
Other - TOI
Total Other Income
More & hidden
Total Other Income
Income Before Interest & Taxes
Income Before Interest & Taxes
More & hidden
Income Before Interest & Taxes
Total Interest and Oth Charges
Interest on long-term debt
419901 - Interco Quip Interest Income
427000 - Interest On Long Term Debt
427001 - Public Service Resources, Inc
427004 - Sale\Leaseback Loc Fees
427007 - Public Svc Resources-Regulato
427008 - Int. exp.-securitization bonds
427100 - First Mortgage Bonds
427198 - Doe Spent Nf Disposal Cost
427200 - Int On Ltd-Nypa Debt
427201 - Int On Ltd-Life Extension
427202 - Int On Ltd-Value Sharing
427300 - Capitalized Interest
427DAA - Interest Expense - DAA
428000 - Amort-Debt Discount & Expense
428100 - Amort Of Loss On Reacq Debt
428101 - Amort Loss 1984 Pc. Bonds
428102 - Amort Loss 1989 Pc. Bonds
428103 - Amort Loss 2004 Pc. Bonds
428107 - Amort Loss 1992-93 Ref-Tx Ret
428108 - Amort Loss 1992-93 Ref-La Ret
428109 - Amort Loss 1992-93 Ref
428110 - Amort Loss 1996 Refunding
428941 - Amort-Debt Sale/Leaseback Exp
428942 - Amort-Debt Sale/Leaseback Loss
429000 - Amort-Premium On Debt-Cr
429100 - Amort- Gain Reacq Debt-Cr
430901 - Interco Quip Interest Expense
431901 - Quip Interest Expense
437004 - Mandatorily redeemable divdnds
Interest on long-term debt
Other interest - net
430000 - Interco Int Exp-Unrelated
43000N - Nuc Trans Int On Debt Assoc Co
430100 - Interco Int Exp-Related
430200 - Interco Int Exp Unrel-Collater
430210 - Gty Fees Expense-Intercompany
430211 - Int Exp - Ip2 Factoring
430212 - Int Exp - Vy Factoring
430300 - Intercompany Interest Expense
430700 - Interest Expense Esi
430ELM - Interest Expense - Affiliate
431000 - Other Interest Expense
(396)
(396)
19,486
19,486
202,692
202,692
202,692
43,825
1,002
41,706
39
948
1,620
45,316
5
273
E-2 Supporting Schedule Page 26 of 30
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41
Schedule E-2 Supporting Schedule
Income Statement - Total Company
Partially Projected Test Year Ended
March 31, 2015
Arkansas Public Service Commission
Minimum Filing Requirements
Entergy Arkansas, Inc.
Docket No. 15-015-U
A0000 - Entergy Arkansas Inc.
Balance in Thousands
6 Mos Ended
9/30/14
Line #
Total Operating Revenues
1328 Total Operating Revenues
431001 - Customer Deposits-Int Exp
1329
431003 - Tax Deficiencies
1330
431006 - Bank Loans - Interest Exp.
1331
431007 - Interest Exp Gg1 Over Collectn
1332
431008 - Interest Expense - Esi
1333
43100N - Nuc Trans- Other Interest Expe
1334
431102 - Nuclear Reserve Int
1335
431200 - Int Exp-Bank Loc
1336
431201 - Int Exp-Decom Liability
1337
431204 - Deferred Contract Revenue
1338
431U39 - Letter Of Credit Exp-Pcb
1339
431U90 - Int Def Compensation Kidco
1340
431U91 - Int Exp Fuel Over Recovery
1341
Other interest - net
1342
Allow bor funds used dur const 4265AD - AFDC Dr Cntra
1343
432000 - Afudc -Borrowed Funds - Cr.
1344
43200N - Nuc Trans- Afudc -Borrowed Fun
1345
432101 - Afudc-Net Bor Funds
1346
432102 - Afudc-Gross Bor Funds
1347
432103 - Afudc-Gross Bor Funds-Bk Only
1348
Allow bor funds used dur const
1349
Total Interest and Oth Charges
1350
More & hidden
1351
Total Interest and Oth Charges
1352 Net Income (Loss) Before TaxesNet Income (Loss) Before Taxes
1353
Net Income (Loss) Before Taxes
1354
More & hidden
1355
Net Income (Loss) Before Taxes
1356 Income Taxes
Income Taxes
1357
Federal Income Taxes
409100 - Income Taxes - Util Op Inc
1358
409105 - Income Taxes - Federal (Below
1359
40910N - Nuc Trans Inc Tax Util Op Inc
1360
409110 - Income Taxes - Federal (Cayman
1361
409111 - Gas-Fed Income Tax
1362
409112 - Income Taxes-Util Op Inc - Fed
1363
409113 - Fo-Fed Income Tax
1364
409114 - Income Taxes-Util Op Inc-State
1365
409120 - Income Taxes Federal (Citipo
1366
409121 - Gas-State Income Tax
1367
409123 - Fo-State Income Tax
1368
409124 - Income Taxes - O I & D
1369
409130 - Income Taxes - Foreign
1370
409131 - INC TAX-UTIL OP INC-IPP
1371
409140 - Inc Tax-Util Op Inc-IPP
1372
409148 - Uncertain Income Taxes-Federal
1373
409149 - Uncertain Income Taxes - State
1374
409300 - Income Taxes - State La
1375
409325 - Income Taxes - State - Ebsi
1376
409350 - Income Taxes - State - Nc
1377
409400 - Income Taxes - State - Va
1378
409401 - Income Taxes - Va Valuation Al
Amounts may not add or tie to other
schedules due to rounding.
30
291
599
808
(2,897)
(2,089)
43,825
43,825
158,866
158,866
158,866
66,889
7,005
4,727
-
E-2 Supporting Schedule Page 27 of 30
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41
Schedule E-2 Supporting Schedule
Income Statement - Total Company
Partially Projected Test Year Ended
March 31, 2015
Arkansas Public Service Commission
Minimum Filing Requirements
Entergy Arkansas, Inc.
Docket No. 15-015-U
A0000 - Entergy Arkansas Inc.
Balance in Thousands
6 Mos Ended
9/30/14
Line #
1379 Total Operating Revenues
1380
1381
1382
1383
1384
1385
1386
1387
1388
1389
1390
1391
1392
1393
1394
1395
1396
1397
1398
1399
1400
1401
1402
1403
1404
1405
1406
1407
1408
1409
1410
1411
1412
1413
1414
1415
1416
1417
1418
1419
1420
1421
1422
1423
1424
1425
1426
1427
1428
1429
Amounts may not add or tie to other
schedules due to rounding.
Total Operating Revenues
409450 - Income Taxes - Mississippi
409455 - Income Taxes - Maine
409500 - Income Taxes Argentina
409510 - Income Taxes - Brazil
409520 - Income Taxes - Netherlands
409530 - Income Taxes - Nl Antilles
409550 - Income Taxes - Uk
409600 - Income Taxes - Peru
409650 - Income Taxes - Pakistan
409700 - Income Taxes - Singapore
431191 - Accrued Interest on UTPs
431193 - Interest Pymts on UTPs - Fed
431194 - Interest Pymts on UTPs - State
Federal Income Taxes
Prov Def Income Taxes
410000 - Prov For Def Income Taxes
410100 - Prov-Def Inc Tax- Util Op Inc
410101 - Prov Defer Inc Taxes-Util-Fed
41010N - Nuc Trns Prv Df In Tx-Ut Op In
410110 - Deferred Income Tax-Federal
410111 - Gas-Def Fed Income Tax
410113 - Fo-Def Fed Income Tax
410120 - Prov Def Inc Tax-Util Op-State
410121 - Gas-Def State Inc Tax
410123 - Fo-State Income Tax
410130 - Def Fed Inc Taxes-Ano Outage
410131 - Prov For Def Inc Taxes-Foreign
410132 - Prov Def Inc Taxes-Federal Val
410133 - Prov Def Inc Taxes-Federal Ftc
410134 - Prov Def Inc Taxes-Fed Ftc Val
410135 - Prov Def Inc Taxes-Foreign Val
410140 - Def St Inc Taxes-Ano Outage
410150 - Deferred Income Tax - Uk
Prov Def Income Taxes
Prov Def Inc Tax Credit
411100 - Prov-Def Inc Tx - Cr - Op Inc
41110N - Nuc Trans Prv Df In Tx-Cr Op I
411110 - Prov Def Inc Tax-Cr-Op Inc-Fed
411120 - Prov Def Inc Tax-Cr-Op Inc-Sta
411136 - ProvDefIncTax-Cr-R-09-136-Fed
Prov Def Inc Tax Credit
Investment Tax Credit
411400 - Itc Adjustments-Util Oper
411430 - Itc Amortization
411431 - Itc Amortization Fo
411432 - Itc Amortization Gas
Investment Tax Credit
Income Taxes (below the line) 409200 - Income Taxes - State Ar
409205 - Income Taxes - State Ar (Below
409210 - Income Taxes-O I & D - Federal
409220 - Income Taxes - O I & D - State
Income Taxes (below the line)
Prov Def Inc Taxes below line 410200 - Prov For Def Inc Tax- O I & D
410205 - Prov Def Inc Taxes-O I & D-Fed
1,500
13,233
287,767
37,796
325,563
(240,148)
(32,395)
(272,544)
(454)
(454)
1,091
1,091
-
E-2 Supporting Schedule Page 28 of 30
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41
Schedule E-2 Supporting Schedule
Income Statement - Total Company
Partially Projected Test Year Ended
March 31, 2015
Arkansas Public Service Commission
Minimum Filing Requirements
Entergy Arkansas, Inc.
Docket No. 15-015-U
A0000 - Entergy Arkansas Inc.
Balance in Thousands
6 Mos Ended
9/30/14
Line #
1430
1431
1432
1433
1434
1435
1436
1437
1438
1439
1440
1441
1442
1443
1444
1445
1446
1447
1448
1449
1450
1451
1452
1453
1454
1455
1456
1457
1458
1459
1460
1461
1462
1463
1464
1465
1466
1467
1468
1469
1470
1471
1472
1473
1474
1475
1476
1477
1478
1479
1480
Total Operating Revenues
Total Operating Revenues
410210 - Prov For Def Inc Tax-Federal
410217 - Deferred Fit-Regulatory Asset
410218 - Prov Def Inc Taxes-O I & D-Sta
410220 - Prov For Def Inc Tax - State
410221 - Prov For Def Inc Tax Tate V
410227 - Deferred Sit-Regulatory Asset
4102U1 - Dfit Advance Royalty Rec
4102U2 - Dfit Depletable Property
4102U3 - Dfit Rental Income
4102U4 - Dfit Depreciable Property
410310 - Prov For Def Inc Tax-State(Mn)
410320 - Prov For Def Inc Tax-State(Ms)
410400 - Deferred Income Taxes-Foreign
Prov Def Inc Taxes below line
Prov Def Inc Tax Cr below line 411200 - Prov-Def Inc Tax-Cr - O I & D
411210 - Prov Def Inc Tax-Cr-O I&D-Fed
411217 - Deferred Fit-Regulatory Asset
411220 - Prov Def Inc Tax-Cr-O I&D-Stat
411227 - Deferred Sit-Regulatory Asset
Prov Def Inc Tax Cr below line
411500 - Itc Adjust-Nonutil Oper
Investment Tax Cr Adj - Net
411510 - Itc Amortization - Rb Abeyed
Investment Tax Cr Adj - Net
Income Taxes
More & hidden
Income Taxes
Net Income Before Acct Chg
Net Income Before Acct Chg
Net Income Before Acct Chg
More & hidden
Net Income Before Acct Chg
Cumml Effect of Acct Chg nt tx Cumml Effect of Acct Chg nt tx
Cumml Effect of Acct Chg nt tx 409X01 - Cumul Effect Taxes-SFAS 143
421X01 - Cumul Effect (a)-SFAS 143
426X01 - Cumul Effect (b)-SFAS 143
Cumml Effect of Acct Chg nt tx
Cumml Effect of Acct Chg nt tx
More & hidden
Cumml Effect of Acct Chg nt tx
Net Income (Loss)
Net Income (Loss)
Net Income (Loss)
More & hidden
Net Income (Loss)
Other
Other
Pref div req of subs and oth
437000 - Dividends Dec-Preferred Stock
437300 - Pref. Stock Dividend-affiliate
437999 - Preferred Dividend Reqts
Pref div req of subs and oth
Other
More & hidden
Other
Net Inc (Loss) Appl to Com Stk Net Inc (Loss) Appl to Com Stk
Amounts may not add or tie to other
schedules due to rounding.
66,889
66,889
91,977
91,977
91,977
91,977
91,977
91,977
3,437
3,437
3,437
3,437
3,437
88,541
E-2 Supporting Schedule Page 29 of 30
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41
Schedule E-2 Supporting Schedule
Income Statement - Total Company
Partially Projected Test Year Ended
March 31, 2015
Arkansas Public Service Commission
Minimum Filing Requirements
Entergy Arkansas, Inc.
Docket No. 15-015-U
A0000 - Entergy Arkansas Inc.
Balance in Thousands
6 Mos Ended
9/30/14
Line #
1481 Total Operating Revenues
1482
1483
1484 Total
Amounts may not add or tie to other
schedules due to rounding.
TotalInc
Operating
Revenues
Net
(Loss) Appl
to Com Stk
More & hidden
Net Inc (Loss) Appl to Com Stk
88,541
88,541
(88,541)
E-2 Supporting Schedule Page 30 of 30
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41
Arkansas Public Service Commission
Minimum Filing Requirements
Entergy Arkansas, Inc.
Docket No. 15-015-U
LN
(1)
Entergy Arkansas, Inc.
Other Income and Deductions
Account
(3)
Actual Amount
Per Financial
Statements for
6 months ending
Sep. 30, 2014
(4)
1
2
3
4
5
6
7
8
9
10
11
12
Description
(2)
Non - Operating Income:
Taxes Other Than Inc- O I & D
Expenses - Non Utility Oper
Nonoperating Rental Income
Equity Earnings Subs Cos
Interest & Dividend Income
Decomm - realized gains/losses
Affiliated Interest Income
Afudc - Other Funds
Misc Nonoperating Income
Royalty Income
Gain On Disposition Of Proprty
Total Other (Income)
408202
4171AM
418000
418100
419000
419003
419011
419100
421000
421340
4211AM
2,612
(40,000)
181,172
(7,218,826)
(9,185,715)
(2,221)
(5,193,530)
(1,015,257)
(162,884)
(11,953)
(22,646,601)
13
14
15
16
17
18
19
20
21
22
23
24
Loss On Disposition Of Proprty
4212AM
Donations
426100
Penalties
426300
Exp-Civic,Political & Rel Act
426400
Other Deductions
426500
AFDC Dr Cntra APSC Ord 09-84-U 4265AD
AFDC Eqty Cntr APSC Or 09-84-U 4265AE
Disallowed EAI Amort Exp
4265AM
Disallowed EAI Depr Exp
4265DP
Disallowed EAI Other Exp
4265OT
Disalow PR Tx APSC Ord 09-84-U 4265TX
Total Other Income Deductions
26,626
429,148
3,262
1,096,459
83,119
807,620
1,717,910
(90,237)
(138,320)
2,258,443
111,995
6,306,025
25
26
27
Income Taxes-O I & D - Federal
Income Taxes - O I & D - State
Total Taxes on Other Income
1,090,828
1,090,828
28
Net Other Income Deductions
29
30
31
32
33
34
35
36
37
38
39
40
41
Interest On Long Term Debt
First Mortgage Bonds
Doe Spent Nf Disposal Cost
Amort-Debt Discount & Expense
Amort Of Loss On Reacq Debt
Interco Int Exp-Unrelated
Other Interest Expense
42
Extraordinary Items
43
Net Non-Operating Income
Bank Loans - Interest Exp.
Accrued Interest on UTPs
Interest Pymts on UTPs - State
Afudc -Borrowed Funds - Cr.
Total Interest Charges
Schedule E-3
Other Income and Deductions
Partially Projected Test Year Ended
March 31, 2015
409210
409220
427000
427100
427198
428000
428100
430000
431000
431003
431006
431191
431194
432000
Projected Activity
for 6 Months
Ending
Mar. 31, 2015
(5)
Total Test
Year
(6)
(5,386,417)
(6,854,036)
(1,657)
(6,411,405)
(18,653,515)
2,612
(40,000)
181,172
(12,605,243)
(16,039,751)
(3,877)
(11,604,935)
(1,015,257)
(162,884)
(11,953)
(41,300,116)
787,597
211,756
1,310,446
873,491
2,120,758
102,344
5,406,391
26,626
1,216,744
215,018
2,406,905
83,119
1,681,111
3,838,669
(90,237)
(138,320)
2,258,443
214,339
11,712,416
924,492
924,492
2,015,320
2,015,320
(15,249,748)
(12,322,631)
(27,572,379)
1,002,299
41,706,083
39,431
947,778
1,620,364
5,001
272,776
29,555
291,417
1,500,000
(2,897,052)
44,517,652
1,069,355
44,496,341
1,476,811
983,622
1,644,698
37,167
289,393
2,071,654
86,202,425
1,516,242
1,931,400
3,265,062
42,168
562,169
29,555
559,445
1,500,000
(6,030,389)
91,649,730
29,267,904
268,028
(3,133,338)
47,132,077
34,809,446
(2,826)
(c)
(c)
(c)
(c)
(c)
(b)
(381,760)
(b)
(384,585)
64,077,350
Supporting Schedules
(a) E-4 - Adjustments are not made to other income and deductions (except interest related)
since they are not included in the cost of service.
(b) ESI interest and credit fees are reclassified to operating expense in the cost of service.
(c) Embedded in cost of capital annualized cost of preferred stock or long term debt.
Amounts may not add or tie to other schedules
due to rounding.
Pro Forma
Adjustments
and Reclassi- Pro Forma
fication (a)
Year
(7)
(8)
(384,585)
Recap Schedules
None
E-3 Page 1 of 1
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41
Schedule E-4
Adjustments to Other Income and Deductions
Partially Projected Test Year Ended
March 31, 2015
Arkansas Public Service Commission
Minimum Filing Requirements
Entergy Arkansas, Inc.
Docket No. 15-015-U
Entergy Arkansas, Inc.
Adjustments to Other Income and Deductions
(1)
(2)
LN
Description
1
2
3
4
5
6
7
8
9
10
11
12
Non - Operating Income:
Taxes Other Than Inc- O I & D
Expenses - Non Utility Oper
Nonoperating Rental Income
Equity Earnings Subs Cos
Interest & Dividend Income
Decomm - realized gains/losses
Affiliated Interest Income
Afudc - Other Funds
Misc Nonoperating Income
Royalty Income
Gain On Disposition Of Proprty
Total Other (Income)
13
14
15
16
17
18
19
20
21
22
23
24
(3)
Account
(4)
Adjustment No.
(5)
Adjustment
Description
(6)
Total Company
Adjustment
(A)
408202
4171AM
418000
418100
419000
419003
419011
419100
421000
421340
4211AM
-
Loss On Disposition Of Proprty
Donations
Penalties
Exp-Civic,Political & Rel Act
Other Deductions
AFDC Dr Cntra APSC Ord 09-84-U
AFDC Eqty Cntr APSC Or 09-84-U
Disallowed EAI Amort Exp
Disallowed EAI Depr Exp
Disallowed EAI Other Exp
Disalow PR Tx APSC Ord 09-84-U
Total Other Income Deductions
4212AM
426100
426300
426400
426500
4265AD
4265AE
4265AM
4265DP
4265OT
4265TX
-
25
26
27
Income Taxes-O I & D - Federal
Income Taxes - O I & D - State
Total Taxes on Other Income
409210
409220
-
28
Net Other Income Deductions
29
30
31
32
33
34
35
36
37
38
39
40
41
Interest On Long Term Debt
First Mortgage Bonds
Doe Spent Nf Disposal Cost
Amort-Debt Discount & Expense
Amort Of Loss On Reacq Debt
Interco Int Exp-Unrelated
Other Interest Expense
42
Extraordinary Items
43
Net Non-Operating Income
Bank Loans - Interest Exp.
Accrued Interest on UTPs
Interest Pymts on UTPs - State
Afudc -Borrowed Funds - Cr.
Total Interest Charges
Supporting Schedules
None
Amounts may not add or tie to other
schedules due to rounding.
427000
427100
427198
428000
428100
430000
431000
431003
431006
431191
431194
432000
AJ06D
Reclass Interest
AJ06D
Reclass Interest
(2,826)
(381,760)
(384,585)
(384,585)
Recap Schedules
(A) E-3
E-4 Page 1 of 1
Arkansas Public Service Commission
Minimum Filing Requirements
Entergy Arkansas, Inc.
Schedule
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc.
41E-5
Docket No. 15-015-U
Audited Financial Statements
See attached EAI Audited Financial Statements excerpt from the 2014 Form 10-K.
E-5 Page 1 of 182
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41
REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM
To the Board of Directors and Shareholders of
Entergy Arkansas, Inc. and Subsidiaries
Little Rock, Arkansas
We have audited the accompanying consolidated balance sheets of Entergy Arkansas, Inc. and Subsidiaries (the
“Company”) as of December 31, 2014 and 2013, and the related consolidated income statements, consolidated
statements of cash flows, and consolidated statements of changes in common equity (pages 316 through 320 and
applicable items in page 61 through 234) for each of the three years in the period ended December 31, 2014. These
financial statements are the responsibility of the Company’s management. Our responsibility is to express an opinion
on these financial statements based on our audits.
We conducted our audits in accordance with the standards of the Public Company Accounting Oversight Board (United
States). Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the
financial statements are free of material misstatement. An audit includes examining, on a test basis, evidence supporting
the amounts and disclosures in the financial statements. An audit also includes assessing the accounting principles
used and significant estimates made by management, as well as evaluating the overall financial statement presentation.
We believe that our audits provide a reasonable basis for our opinion.
In our opinion, such consolidated financial statements present fairly, in all material respects, the financial position of
Entergy Arkansas, Inc. and Subsidiaries as of December 31, 2014 and 2013, and the results of their operations and
their cash flows for each of the three years in the period ended December 31, 2014, in conformity with accounting
principles generally accepted in the United States of America.
/s/ DELOITTE & TOUCHE LLP
New Orleans, Louisiana
February 26, 2015
315
E-5 Page 2 of 182
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41
ENTERGY ARKANSAS, INC. AND SUBSIDIARIES
CONSOLIDATED INCOME STATEMENTS
For the Years Ended December 31,
2014
2013
2012
(In Thousands)
OPERATING REVENUES
Electric
$2,172,391
OPERATING EXPENSES
Operation and Maintenance:
Fuel, fuel-related expenses, and gas purchased for resale
Purchased power
Nuclear refueling outage expenses
Other operation and maintenance
Decommissioning
Taxes other than income taxes
Depreciation and amortization
Other regulatory credits - net
TOTAL
OPERATING INCOME
$2,190,159
$2,127,004
327,695
528,815
43,258
647,461
46,972
91,470
236,770
(20,054)
1,902,387
426,316
473,326
40,499
592,892
43,058
89,471
230,512
(10,975)
1,885,099
480,464
431,932
47,103
545,782
40,484
89,527
222,734
(38,406)
1,819,620
270,004
305,060
307,384
OTHER INCOME
Allowance for equity funds used during construction
Interest and investment income
Miscellaneous - net
TOTAL
7,238
23,075
(5,144)
25,169
10,913
30,148
(4,275)
36,786
9,070
15,169
(4,049)
20,190
INTEREST EXPENSE
Interest expense
Allowance for borrowed funds used during construction
TOTAL
93,921
(3,769)
90,152
91,318
(3,207)
88,111
82,860
(2,457)
80,403
INCOME BEFORE INCOME TAXES
Income taxes
NET INCOME
Preferred dividend requirements
EARNINGS APPLICABLE TO COMMON STOCK
205,021
253,735
247,171
83,629
91,787
94,806
121,392
161,948
152,365
6,873
6,873
6,873
$114,519
$155,075
$145,492
See Notes to Financial Statements.
316
E-5 Page 3 of 182
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41
ENTERGY ARKANSAS, INC. AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF CASH FLOWS
For the Years Ended December 31,
2014
2013
2012
(In Thousands)
OPERATING ACTIVITIES
Net income
Adjustments to reconcile net income to net cash flow provided by
operating activities:
Depreciation, amortization, and decommissioning, including nuclear fuel
amortization
Deferred income taxes, investment tax credits, and non-current taxes
accrued
Changes in assets and liabilities:
Receivables
Fuel inventory
Accounts payable
Prepaid taxes and taxes accrued
Interest accrued
Deferred fuel costs
Other working capital accounts
Provisions for estimated losses
Other regulatory assets
Pension and other postretirement liabilities
Other assets and liabilities
Net cash flow provided by operating activities
INVESTING ACTIVITIES
Construction expenditures
Allowance for equity funds used during construction
Nuclear fuel purchases
Proceeds from sale of nuclear fuel
Proceeds from nuclear decommissioning trust fund sales
Investment in nuclear decommissioning trust funds
Payment for purchase of plant
Change in money pool receivable - net
Changes in securitization account
Litigation proceeds for reimbursement of spent nuclear fuel storage costs
Counterparty collateral deposit
Insurance proceeds
Other
Net cash flow used in investing activities
FINANCING ACTIVITIES
Proceeds from the issuance of long-term debt
Retirement of long-term debt
Changes in short-term borrowings - net
Dividends paid:
Common stock
Preferred stock
Other
Net cash flow provided by financing activities
Net increase in cash and cash equivalents
Cash and cash equivalents at beginning of period
Cash and cash equivalents at end of period
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION:
Cash paid (received) during the period for:
Interest - net of amount capitalized
Income taxes
See Notes to Financial Statements.
317
$121,392
$161,948
$152,365
387,945
357,639
357,913
130,132
130,707
(67,482)
25,661
(9,394)
(120,097)
14,261
(1,786)
(140,483)
72,411
(57)
(367,234)
252,639
38,436
403,826
(26,320)
7,471
141,041
(204,990)
(6,382)
28,609
(34,909)
(76)
214,131
(295,435)
(72,184)
401,250
(30,786)
(68)
(179,009)
178,688
(1,463)
112,471
55,735
182
(88,119)
75,725
(57,035)
509,117
(535,464)
10,789
(195,092)
75,860
181,489
(190,062)
—
15,313
(261)
—
—
36,600
200
(600,628)
(489,079)
14,550
(88,637)
36,478
266,391
(274,519)
—
(9,496)
568
10,271
9,000
—
—
(524,473)
(361,858)
12,441
(215,968)
96,700
144,275
(154,608)
(253,043)
9,327
(514)
—
—
—
—
(723,248)
707,465
(447,815)
47,968
716,595
(442,302)
(36,735)
252,347
(12,230)
2,821
(10,000)
(6,873)
(2,460)
288,285
91,483
127,022
$218,505
(15,000)
(6,873)
27
215,712
92,489
34,533
$127,022
(10,000)
(6,873)
—
226,065
11,934
22,599
$34,533
$90,285
($48,948)
$92,353
$184,592
$79,271
($20,480)
E-5 Page 4 of 182
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41
ENTERGY ARKANSAS, INC. AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
ASSETS
December 31,
2014
2013
(In Thousands)
CURRENT ASSETS
Cash and cash equivalents:
Cash
Temporary cash investments
Total cash and cash equivalents
Securitization recovery trust account
Accounts receivable:
Customer
Allowance for doubtful accounts
Associated companies
Other
Accrued unbilled revenues
Total accounts receivable
Accumulated deferred income taxes
Deferred fuel costs
Fuel inventory - at average cost
Materials and supplies - at average cost
Deferred nuclear refueling outage costs
System agreement cost equalization
Prepayments and other
TOTAL
OTHER PROPERTY AND INVESTMENTS
Decommissioning trust funds
Other
TOTAL
$10,526
207,979
218,505
4,096
$4,181
122,841
127,022
3,835
97,314
(32,247)
32,187
110,269
80,704
288,227
21,533
143,279
50,898
162,792
29,690
—
9,588
928,608
102,328
(30,113)
68,875
94,256
82,298
317,644
33,556
68,696
41,504
152,429
31,135
30,000
58,911
864,732
769,883
14,170
784,053
710,913
30,845
741,758
9,139,181
961
284,322
293,695
9,718,159
4,191,959
5,526,200
8,798,458
1,064
209,036
321,901
9,330,459
4,034,880
5,295,579
64,214
73,864
1,391,276
65,900
47,674
1,569,064
1,014,392
—
44,565
1,132,821
$8,807,925
$8,034,890
UTILITY PLANT
Electric
Property under capital lease
Construction work in progress
Nuclear fuel
TOTAL UTILITY PLANT
Less - accumulated depreciation and amortization
UTILITY PLANT - NET
DEFERRED DEBITS AND OTHER ASSETS
Regulatory assets:
Regulatory asset for income taxes - net
Other regulatory assets (includes securitization property of $67,877 as of December 31,
2014 and $80,963 as of December 31, 2013)
Deferred fuel costs
Other
TOTAL
TOTAL ASSETS
See Notes to Financial Statements.
318
E-5 Page 5 of 182
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41
ENTERGY ARKANSAS, INC. AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
LIABILITIES AND EQUITY
December 31,
2014
2013
(In Thousands)
CURRENT LIABILITIES
Currently maturing long-term debt
Short-term borrowings
Accounts payable:
Associated companies
Other
Customer deposits
Taxes accrued
Accumulated deferred income taxes
Interest accrued
Other
TOTAL
NON-CURRENT LIABILITIES
Accumulated deferred income taxes and taxes accrued
Accumulated deferred investment tax credits
Other regulatory liabilities
Decommissioning
Accumulated provisions
Pension and other postretirement liabilities
Long-term debt (includes securitization bonds of $76,164 as of December 31, 2014 and
$88,961 as of December 31, 2013)
Other
TOTAL
$—
47,968
$70,000
—
56,078
174,998
115,647
24,240
15,009
20,250
27,872
482,062
149,802
228,160
86,512
9,979
9,231
22,036
55,656
631,376
1,997,983
37,708
254,036
818,351
5,689
571,870
1,906,562
38,958
219,370
723,771
5,746
319,211
2,671,343
28,296
6,385,276
2,335,802
18,026
5,567,446
116,350
116,350
470
588,471
1,235,296
1,824,237
470
588,471
1,130,777
1,719,718
$8,807,925
$8,034,890
Commitments and Contingencies
Preferred stock without sinking fund
COMMON EQUITY
Common stock, $0.01 par value, authorized 325,000,000 shares; issued and outstanding
46,980,196 shares in 2014 and 2013
Paid-in capital
Retained earnings
TOTAL
TOTAL LIABILITIES AND EQUITY
See Notes to Financial Statements.
319
E-5 Page 6 of 182
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41
ENTERGY ARKANSAS, INC. AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF CHANGES IN COMMON EQUITY
For the Years Ended December 31, 2014, 2013, and 2012
Common
Stock
Balance at December 31, 2011
Net income
Common stock dividends
Preferred stock dividends
Balance at December 31, 2012
Net income
Common stock dividends
Preferred stock dividends
Other
Balance at December 31, 2013
Net income
Common stock dividends
Preferred stock dividends
Balance at December 31, 2014
$470
—
—
—
$470
—
—
—
—
$470
—
—
—
$470
Common Equity
Paid-in
Capital
(In Thousands)
$588,444
—
—
—
$588,444
—
—
—
27
$588,471
—
—
—
$588,471
Retained
Earnings
$855,210
152,365
(10,000)
(6,873)
$990,702
161,948
(15,000)
(6,873)
—
$1,130,777
121,392
(10,000)
(6,873)
$1,235,296
Total
$1,444,124
152,365
(10,000)
(6,873)
$1,579,616
161,948
(15,000)
(6,873)
27
$1,719,718
121,392
(10,000)
(6,873)
$1,824,237
See Notes to Financial Statements.
320
E-5 Page 7 of 182
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41
ENTERGY ARKANSAS, INC. AND SUBSIDIARIES
SELECTED FINANCIAL DATA - FIVE-YEAR COMPARISON
2014
Operating revenues
Net Income
Total assets
Long-term obligations (a)
2013
$2,172,391
$121,392
$8,807,925
$2,787,693
2012
(In Thousands)
$2,190,159
$161,948
$8,034,890
$2,452,152
$2,127,004
$152,365
$7,819,445
$1,910,245
2011
$2,084,310
$164,891
$7,212,212
$1,992,271
2010
$2,082,447
$172,618
$6,751,368
$1,946,494
(a) Includes long-term debt (excluding currently maturing debt) and preferred stock without sinking fund.
2014
2013
2012
(Dollars In Millions)
2011
2010
Electric Operating Revenues:
Residential
Commercial
Industrial
Governmental
Total retail
$755
461
424
18
1,658
$772
469
433
19
1,693
$766
472
439
20
1,697
$756
450
421
20
1,647
$773
441
415
20
1,649
Sales for resale:
Associated companies
Non-associated companies
Other
Total
131
282
101
$2,172
346
83
68
$2,190
320
49
61
$2,127
279
96
62
$2,084
302
78
53
$2,082
8,070
5,934
6,808
238
21,050
7,921
5,929
6,769
241
20,860
7,859
6,046
6,925
257
21,087
8,229
6,051
7,029
275
21,584
8,501
6,144
7,082
277
22,004
2,299
8,003
31,352
7,918
1,011
29,789
7,926
1,093
30,106
6,893
1,304
29,781
7,853
850
30,707
Billed Electric Energy Sales (GWh):
Residential
Commercial
Industrial
Governmental
Total retail
Sales for resale:
Associated companies
Non-associated companies
Total
321
E-5 Page 8 of 182
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41
ENTERGY CORPORATION AND SUBSIDIARIES
NOTES TO FINANCIAL STATEMENTS
NOTE 1. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Entergy Corporation, Entergy
Arkansas, Entergy Gulf States Louisiana, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans,
Entergy Texas, and System Energy)
The accompanying consolidated financial statements include the accounts of Entergy Corporation and its
subsidiaries. As required by generally accepted accounting principles in the United States of America, all intercompany
transactions have been eliminated in the consolidated financial statements. Entergy’s Registrant Subsidiaries (Entergy
Arkansas, Entergy Gulf States Louisiana, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy
Texas, and System Energy) also include their separate financial statements in this Form 10-K. The Registrant
Subsidiaries and many other Entergy subsidiaries maintain accounts in accordance with FERC and other regulatory
guidelines.
Use of Estimates in the Preparation of Financial Statements
In conformity with generally accepted accounting principles in the United States of America, the preparation
of Entergy Corporation’s consolidated financial statements and the separate financial statements of the Registrant
Subsidiaries requires management to make estimates and assumptions that affect the reported amounts of assets,
liabilities, revenues, and expenses and the disclosure of contingent assets and liabilities. Adjustments to the reported
amounts of assets and liabilities may be necessary in the future to the extent that future estimates or actual results are
different from the estimates used.
Revenues and Fuel Costs
Entergy Arkansas, Entergy Gulf States Louisiana, Entergy Louisiana, Entergy Mississippi, and Entergy Texas
generate, transmit, and distribute electric power primarily to retail customers in Arkansas, Louisiana, Louisiana,
Mississippi, and Texas, respectively. Entergy Gulf States Louisiana also distributes natural gas to retail customers in
and around Baton Rouge, Louisiana. Entergy New Orleans sells both electric power and natural gas to retail customers
in the City of New Orleans, except for Algiers, where Entergy Louisiana is the electric power supplier. The Entergy
Wholesale Commodities segment derives almost all of its revenue from sales of electric power generated by plants
owned by subsidiaries in that segment.
Entergy recognizes revenue from electric power and natural gas sales when power or gas is delivered to
customers. To the extent that deliveries have occurred but a bill has not been issued, Entergy’s Utility operating
companies accrue an estimate of the revenues for energy delivered since the latest billings. The Utility operating
companies calculate the estimate based upon several factors including billings through the last billing cycle in a month,
actual generation in the month, historical line loss factors, and prices in effect in Entergy’s Utility operating companies’
various jurisdictions. Changes are made to the inputs in the estimate as needed to reflect changes in billing
practices. Each month the estimated unbilled revenue amounts are recorded as revenue and unbilled accounts
receivable, and the prior month’s estimate is reversed. Therefore, changes in price and volume differences resulting
from factors such as weather affect the calculation of unbilled revenues from one period to the next, and may result in
variability in reported revenues from one period to the next as prior estimates are reversed and new estimates recorded.
Entergy records revenue from sales under rates implemented subject to refund less estimated amounts accrued
for probable refunds when Entergy believes it is probable that revenues will be refunded to customers based upon the
status of the rate proceeding as of the date the financial statements are prepared.
Entergy’s Utility operating companies’ rate schedules include either fuel adjustment clauses or fixed fuel
factors, which allow either current recovery in billings to customers or deferral of fuel costs until the costs are billed
to customers. Where the fuel component of revenues is billed based on a pre-determined fuel cost (fixed fuel factor),
61
E-5 Page 9 of 182
Entergy Corporation and Subsidiaries
Notes to Financial Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41
the fuel factor remains in effect until changed as part of a general rate case, fuel reconciliation, or fixed fuel factor
filing. System Energy’s operating revenues are intended to recover from Entergy Arkansas, Entergy Louisiana, Entergy
Mississippi, and Entergy New Orleans operating expenses and capital costs attributable to Grand Gulf. The capital
costs are computed by allowing a return on System Energy’s common equity funds allocable to its net investment in
Grand Gulf, plus System Energy’s effective interest cost for its debt allocable to its investment in Grand Gulf.
Accounting for MISO transactions
In December 2013, Entergy joined MISO, a regional transmission organization that maintains functional control
over the combined transmission systems of its members and manages one of the largest energy markets in the U.S. In
the MISO market, Entergy offers its generation and bids its load into the market on an hourly basis. MISO settles these
hourly offers and bids based on locational marginal prices, which is pricing for energy at a given location based on a
market clearing price that takes into account physical limitations on the transmission system, generation, and demand
throughout the MISO region. MISO evaluates the market participants’ energy offers and demand bids to economically
and reliably dispatch the entire MISO system. Entergy nets purchases and sales within the MISO market on an hourly
basis and reports in operating revenues when in a net selling position and in operating expenses when in a net purchasing
position.
Property, Plant, and Equipment
Property, plant, and equipment is stated at original cost. Depreciation is computed on the straight-line basis
at rates based on the applicable estimated service lives of the various classes of property. For the Registrant Subsidiaries,
the original cost of plant retired or removed, less salvage, is charged to accumulated depreciation. Normal maintenance,
repairs, and minor replacement costs are charged to operating expenses. Substantially all of the Registrant Subsidiaries’
plant is subject to mortgage liens.
Electric plant includes the portions of Grand Gulf and Waterford 3 that have been sold and leased back. For
financial reporting purposes, these sale and leaseback arrangements are reflected as financing transactions.
Net property, plant, and equipment for Entergy (including property under capital lease and associated
accumulated amortization) by business segment and functional category, as of December 31, 2014 and 2013, is shown
below:
2014
Production
Nuclear
Other
Transmission
Distribution
Other
Construction work in progress
Nuclear fuel
Property, plant, and equipment - net
Entergy
$9,639
3,425
4,197
6,973
1,521
1,426
1,542
$28,723
62
Entergy
Wholesale
Utility
Commodities
(In Millions)
$6,586
3,067
4,164
6,973
1,373
969
840
$23,972
$3,053
358
33
—
145
456
702
$4,747
Parent &
Other
$—
—
—
—
3
1
—
$4
E-5 Page 10 of 182
Entergy Corporation and Subsidiaries
Notes to Financial
Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc.
41
2013
Entergy
Wholesale
Utility
Commodities
(In Millions)
Entergy
Production
Nuclear
Other
Transmission
Distribution
Other
Construction work in progress
Nuclear fuel
Property, plant, and equipment - net
$9,667
2,836
3,929
6,716
1,652
1,515
1,567
$27,882
$6,601
2,465
3,894
6,716
1,475
1,217
855
$23,223
Parent &
Other
$3,066
371
35
—
174
298
712
$4,656
$—
—
—
—
3
—
—
$3
Depreciation rates on average depreciable property for Entergy approximated 2.8% in 2014, 2.6% in 2013,
and 2.5% in 2012. Included in these rates are the depreciation rates on average depreciable Utility property of 2.5%
in 2014, 2.5% in 2013, and 2.4% 2012, and the depreciation rates on average depreciable Entergy Wholesale
Commodities property of 5.5% in 2014, 4.1% in 2013, and 3.5% in 2012. The increase in 2014 for Entergy Wholesale
Commodities resulted from implementation of a new depreciation study.
Entergy amortizes nuclear fuel using a units-of-production method. Nuclear fuel amortization is included in
fuel expense in the income statements.
“Non-utility property - at cost (less accumulated depreciation)” for Entergy is reported net of accumulated
depreciation of $185.5 million and $203 million as of December 31, 2014 and 2013, respectively.
Construction expenditures included in accounts payable is $209 million and $166 million at December 31,
2014 and 2013, respectively.
Net property, plant, and equipment for the Registrant Subsidiaries (including property under capital lease and
associated accumulated amortization) by company and functional category, as of December 31, 2014 and 2013, is
shown below:
2014
Production
Nuclear
Other
Transmission
Distribution
Other
Construction work in
progress
Nuclear fuel
Property, plant, and
equipment - net
Entergy
Arkansas
Entergy
Gulf States Entergy
Louisiana Louisiana
Entergy
Mississippi
(In Millions)
Entergy
New
Orleans
System
Energy
$—
399
695
1,116
98
$1,935
—
48
—
17
$1,097
593
1,166
1,928
164
$1,403
282
711
1,004
173
$2,151
1,279
859
1,443
287
$—
526
642
1,125
194
284
294
127
132
242
163
68
—
19
—
125
—
50
251
$5,526
$3,832
$6,424
$2,555
$590
$2,433
$2,301
63
$—
(11)
44
357
181
Entergy
Texas
E-5 Page 11 of 182
Entergy Corporation and Subsidiaries
Notes to Financial Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41
2013
Entergy
Arkansas
Entergy
Gulf States
Louisiana
$1,047
609
1,086
1,831
192
$1,422
271
646
950
184
$2,202
684
770
1,420
292
$—
537
638
1,096
197
209
322
105
197
673
147
37
—
$5,296
$3,775
$6,188
$2,505
Production
Nuclear
Other
Transmission
Distribution
Other
Construction work in
progress
Nuclear fuel
Property, plant, and
equipment - net
Entergy
Entergy
Louisiana Mississippi
(In Millions)
Entergy
New
Orleans
Entergy
Texas
System
Energy
$—
371
673
1,079
106
$1,930
—
49
—
17
29
—
95
—
29
189
$574
$2,324
$2,214
$—
(7)
31
340
181
Depreciation rates on average depreciable property for the Registrant Subsidiaries are shown below:
2014
2013
2012
Entergy
Arkansas
2.4%
2.5%
2.5%
Entergy
Gulf States
Louisiana
1.8%
1.8%
1.8%
Entergy
Louisiana
2.5%
2.5%
2.4%
Entergy
Mississippi
2.6%
2.6%
2.6%
Entergy
New
Orleans
3.1%
3.0%
3.0%
Entergy
Texas
2.5%
2.5%
2.4%
System
Energy
3.0%
2.8%
2.8%
Non-utility property - at cost (less accumulated depreciation) for Entergy Gulf States Louisiana is reported net
of accumulated depreciation of $151 million and $146 million as of December 31, 2014 and 2013, respectively. Nonutility property - at cost (less accumulated depreciation) for Entergy Louisiana is reported net of accumulated
depreciation of $3.2 million and $3 million as of December 31, 2014 and 2013, respectively. Non-utility property - at
cost (less accumulated depreciation) for Entergy Mississippi is reported net of accumulated depreciation of $2.2 million
and $2.1 million as of December 31, 2014 and 2013, respectively. Non-utility property - at cost (less accumulated
depreciation) for Entergy Texas is reported net of accumulated depreciation of $10.4 million and $10.4 million as of
December 31, 2014 and 2013, respectively.
As of December 31, 2014, construction expenditures included in accounts payable are $37.3 million for Entergy
Arkansas, $23.4 million for Entergy Gulf States Louisiana, $48 million for Entergy Louisiana, $7.8 million for Entergy
Mississippi, $0.9 million for Entergy New Orleans, $24.1 million for Entergy Texas, and $7.7 million for System
Energy. As of December 31, 2013, construction expenditures included in accounts payable are $61.9 million for Entergy
Arkansas, $13.1 million for Entergy Gulf States Louisiana, $31.1 million for Entergy Louisiana, $2.8 million for
Entergy Mississippi, $1.7 million for Entergy New Orleans, $10.9 million for Entergy Texas, and $6.7 million for
System Energy.
Jointly-Owned Generating Stations
Certain Entergy subsidiaries jointly own electric generating facilities with affiliates or third parties. The
investments and expenses associated with these generating stations are recorded by the Entergy subsidiaries to the
extent of their respective undivided ownership interests. As of December 31, 2014, the subsidiaries’ investment and
accumulated depreciation in each of these generating stations were as follows:
64
E-5 Page 12 of 182
Entergy Corporation and Subsidiaries
Notes to Financial
Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc.
41
Generating Stations
Utility business:
Entergy Arkansas Independence
White Bluff
Ouachita (b)
Entergy Gulf States
Louisiana Roy S. Nelson
Roy S. Nelson
Big Cajun 2
Ouachita (b)
Entergy Louisiana Acadia
Unit 1
Common
Facilities
Units 1 and 2
Common
Facilities
Unit 6
Unit 6 Common
Facilities
Unit 3
Common
Facilities
Common
Facilities
Entergy Mississippi Independence
Units 1 and 2
and Common
Facilities
Entergy Texas Roy S. Nelson
Unit 6
Roy S. Nelson
Unit 6
Common
Facilities
Big Cajun 2
Unit 3
System Energy Grand Gulf
Unit 1
Entergy Wholesale
Commodities:
Independence
Unit 2
Independence
Common
Facilities
Roy S. Nelson
Unit 6
Roy S. Nelson
Unit 6
Common
Facilities
(a)
(b)
FuelType
Total
Megawatt
Capability
(a)
Ownership
Accumulated
Investment Depreciation
(In Millions)
Coal
Coal
839
31.50%
15.75%
$129
$34
$98
$26
Coal
1,637
57.00%
$503
$355
66.67%
$169
$145
537
40.25%
$261
$181
594
17.70%
24.15%
$10
$149
$4
$105
Gas
33.33%
$87
$74
Gas
50.00%
$19
$—
Gas
Coal
Coal
Coal
Coal
1,681
25.00%
$251
$149
Coal
537
29.75%
$188
$115
Coal
Coal
594
13.07%
17.85%
$6
$112
$2
$72
$4,819
$2,820
Nuclear
1,409
Coal
Coal
Coal
Coal
90.00% (c)
842
14.37%
$69
$46
537
7.18%
10.9%
$16
$107
$11
$57
4.79%
$2
$1
“Total Megawatt Capability” is the dependable load carrying capability as demonstrated under actual operating
conditions based on the primary fuel (assuming no curtailments) that each station was designed to utilize.
Ouachita Units 1 and 2 are owned 100% by Entergy Arkansas and Ouachita Unit 3 is owned 100% by Entergy
Gulf States Louisiana. The investment and accumulated depreciation numbers above are only for the common
facilities and not for the generating units.
65
E-5 Page 13 of 182
Entergy Corporation and Subsidiaries
Notes to Financial Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41
(c)
Includes a leasehold interest held by System Energy. System Energy’s Grand Gulf lease obligations are
discussed in Note 10 to the financial statements.
Nuclear Refueling Outage Costs
Nuclear refueling outage costs are deferred during the outage and amortized over the estimated period to the
next outage because these refueling outage expenses are incurred to prepare the units to operate for the next operating
cycle without having to be taken off line.
Allowance for Funds Used During Construction (AFUDC)
AFUDC represents the approximate net composite interest cost of borrowed funds and a reasonable return on
the equity funds used for construction by the Registrant Subsidiaries. AFUDC increases both the plant balance and
earnings and is realized in cash through depreciation provisions included in the rates charged to customers.
Income Taxes
Entergy Corporation and the majority of its subsidiaries file a United States consolidated federal income tax
return. Each tax-paying entity records income taxes as if it were a separate taxpayer and consolidating adjustments
are allocated to the tax filing entities in accordance with Entergy’s intercompany income tax allocation
agreement. Deferred income taxes are recorded for temporary differences between the book and tax basis of assets
and liabilities, and for certain losses and credits available for carryforward.
Deferred tax assets are reduced by a valuation allowance when, in the opinion of management, it is more likely
than not that some portion of the deferred tax assets will not be realized. Deferred tax assets and liabilities are adjusted
for the effects of changes in tax laws and rates in the period in which the tax or rate was enacted.
The benefits of investment tax credits are deferred and amortized over the average useful life of the related
property, as a reduction of income tax expense, for such credits associated with regulated operations in accordance
with ratemaking treatment.
Earnings per Share
The following table presents Entergy’s basic and diluted earnings per share calculation included on the
consolidated statements of income:
For the Years Ended December 31,
2014
2013
(In Millions, Except Per Share Data)
$/share
$/share
Net income attributable to Entergy
Corporation
Basic earnings per average
common share
Average dilutive effect of:
Stock options
Other equity plans
Diluted earnings per average
common shares
$940.7
179.5
0.3
0.5
180.3
$711.9
$5.24
(0.01)
(0.01)
$5.22
2012
$/share
$846.7
178.2
$3.99
177.3
0.1
0.3
—
—
0.3
0.1
178.6
$3.99
177.7
$4.77
(0.01)
—
$4.76
The calculation of diluted earnings per share excluded 5,743,013 options outstanding at December 31, 2014,
8,866,542 options outstanding at December 31, 2013, and 7,164,319 options outstanding at December 31, 2012 that
66
E-5 Page 14 of 182
Entergy Corporation and Subsidiaries
Notes to Financial
Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc.
41
could potentially dilute basic earnings per share in the future. Those options were not included in the calculation of
diluted earnings per share because the exercise price of those options exceeded the average market price for the year.
Stock-based Compensation Plans
Entergy grants stock options, restricted stock, performance units, and restricted liability awards to key
employees of the Entergy subsidiaries under its Equity Ownership Plans, which are shareholder-approved stock-based
compensation plans. These plans are described more fully in Note 12 to the financial statements. The cost of the stockbased compensation is charged to income over the vesting period. Awards under Entergy’s plans generally vest over
3 years.
Accounting for the Effects of Regulation
Entergy’s Utility operating companies and System Energy are rate-regulated enterprises whose rates meet three
criteria specified in accounting standards. The Utility operating companies and System Energy have rates that (i) are
approved by a body (its regulator) empowered to set rates that bind customers; (ii) are cost-based; and (iii) can be
charged to and collected from customers. These criteria may also be applied to separable portions of a utility’s business,
such as the generation or transmission functions, or to specific classes of customers. Because the Utility operating
companies and System Energy meet these criteria, each of them capitalizes costs that would otherwise be charged to
expense if the rate actions of its regulator make it probable that those costs will be recovered in future revenue. Such
capitalized costs are reflected as regulatory assets in the accompanying financial statements. When an enterprise
concludes that recovery of a regulatory asset is no longer probable, the regulatory asset must be removed from the
entity’s balance sheet.
An enterprise that ceases to meet the three criteria for all or part of its operations should report that event in
its financial statements. In general, the enterprise no longer meeting the criteria should eliminate from its balance sheet
all regulatory assets and liabilities related to the applicable operations. Additionally, if it is determined that a regulated
enterprise is no longer recovering all of its costs, it is possible that an impairment may exist that could require further
write-offs of plant assets.
Entergy Gulf States Louisiana does not apply regulatory accounting standards to the Louisiana retail deregulated
portion of River Bend, the 30% interest in River Bend formerly owned by Cajun, and its steam business, unless specific
cost recovery is provided for in tariff rates. The Louisiana retail deregulated portion of River Bend is operated under
a deregulated asset plan representing a portion (approximately 15%) of River Bend plant costs, generation, revenues,
and expenses established under a 1992 LPSC order. The plan allows Entergy Gulf States Louisiana to sell the electricity
from the deregulated assets to Louisiana retail customers at 4.6 cents per kWh or off-system at higher prices, with
certain provisions for sharing incremental revenue above 4.6 cents per kWh between customers and shareholders.
Regulatory Asset for Income Taxes
Accounting standards for income taxes provide that a regulatory asset or liability be recorded if it is probable
that the currently determinable future increase or decrease in regulatory income tax expense will be recovered from
or reimbursed to customers through future rates. The primary source of Entergy’s regulatory asset for income taxes
is related to the ratemaking treatment of the tax effects of book depreciation for the equity component of AFUDC that
has been capitalized to property, plant, and equipment but for which there is no corresponding tax basis. EquityAFUDC is a component of property, plant, and equipment that is included in rate base when the plant is placed in
service.
Cash and Cash Equivalents
Entergy considers all unrestricted highly liquid debt instruments with an original maturity of three months or
less at date of purchase to be cash equivalents.
67
E-5 Page 15 of 182
Entergy Corporation and Subsidiaries
Notes to Financial Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41
Allowance for Doubtful Accounts
The allowance for doubtful accounts reflects Entergy’s best estimate of losses on the accounts receivable
balances. The allowance is based on accounts receivable agings, historical experience, and other currently available
evidence. Utility operating company customer accounts receivable are written off consistent with approved regulatory
requirements.
Investments
Entergy records decommissioning trust funds on the balance sheet at their fair value. Because of the ability
of the Registrant Subsidiaries to recover decommissioning costs in rates and in accordance with the regulatory treatment
for decommissioning trust funds, the Registrant Subsidiaries record an offsetting amount in other regulatory liabilities/
assets for the unrealized gains/(losses) on investment securities. For the 30% interest in River Bend formerly owned
by Cajun, Entergy Gulf States Louisiana has recorded an offsetting amount in other deferred credits for the unrealized
gains/(losses). Decommissioning trust funds for Pilgrim, Indian Point 2, Vermont Yankee, and Palisades do not meet
the criteria for regulatory accounting treatment. Accordingly, unrealized gains recorded on the assets in these trust
funds are recognized in the accumulated other comprehensive income component of equity because these assets are
classified as available for sale. Unrealized losses (where cost exceeds fair market value) on the assets in these trust
funds are also recorded in the accumulated other comprehensive income component of equity unless the unrealized
loss is other than temporary and therefore recorded in earnings. The assessment of whether an investment in a debt
security has suffered an other-than-temporary impairment is based on whether Entergy has the intent to sell or more
likely than not will be required to sell the debt security before recovery of its amortized costs. Further, if Entergy does
not expect to recover the entire amortized cost basis of the debt security, an other-than-temporary impairment is
considered to have occurred and it is measured by the present value of cash flows expected to be collected less the
amortized cost basis (credit loss). The assessment of whether an investment in an equity security has suffered an otherthan-temporary impairment is based on a number of factors including, first, whether Entergy has the ability and intent
to hold the investment to recover its value, the duration and severity of any losses, and, then, whether it is expected
that the investment will recover its value within a reasonable period of time. Entergy’s trusts are managed by third
parties who operate in accordance with agreements that define investment guidelines and place restrictions on the
purchases and sales of investments. See Note 17 to the financial statements for details on the decommissioning trust
funds.
Equity Method Investments
Entergy owns investments that are accounted for under the equity method of accounting because Entergy’s
ownership level results in significant influence, but not control, over the investee and its operations. Entergy records
its share of the investee's comprehensive earnings and losses in income and as an increase or decrease to the investment
account. Any cash distributions are charged against the investment account. Entergy discontinues the recognition of
losses on equity investments when its share of losses equals or exceeds its carrying amount for an investee plus any
advances made or commitments to provide additional financial support. See Note 14 to the financial statements for
additional information regarding Entergy’s equity method investments.
Derivative Financial Instruments and Commodity Derivatives
The accounting standards for derivative instruments and hedging activities require that all derivatives be
recognized at fair value on the balance sheet, either as assets or liabilities, unless they meet various exceptions including
the normal purchase, normal sales criteria. The changes in the fair value of recognized derivatives are recorded each
period in current earnings or other comprehensive income, depending on whether a derivative is designated as part of
a hedge transaction and the type of hedge transaction. Due to regulatory treatment, an offsetting regulatory asset or
liability is recorded for changes in fair value of recognized derivatives for the Registrant Subsidiaries.
68
E-5 Page 16 of 182
Entergy Corporation and Subsidiaries
Notes to Financial
Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc.
41
Contracts for commodities that will be physically delivered in quantities expected to be used or sold in the
ordinary course of business, including certain purchases and sales of power and fuel, meet the normal purchase, normal
sales criteria and are not recognized on the balance sheet. Revenues and expenses from these contracts are reported
on a gross basis in the appropriate revenue and expense categories as the commodities are received or delivered.
For other contracts for commodities in which Entergy is hedging the variability of cash flows related to a
variable-rate asset, liability, or forecasted transactions that qualify as cash flow hedges, the changes in the fair value
of such derivative instruments are reported in other comprehensive income. To qualify for hedge accounting, the
relationship between the hedging instrument and the hedged item must be documented to include the risk management
objective and strategy and, at inception and on an ongoing basis, the effectiveness of the hedge in offsetting the changes
in the cash flows of the item being hedged. Gains or losses accumulated in other comprehensive income are reclassified
to earnings in the periods when the underlying transactions actually occur. The ineffective portions of all hedges are
recognized in current-period earnings. Changes in the fair value of derivative instruments that are not designated as
cash flow hedges are recorded in current-period earnings on a mark-to-market basis.
Entergy has determined that contracts to purchase uranium do not meet the definition of a derivative under the
accounting standards for derivative instruments because they do not provide for net settlement and the uranium markets
are not sufficiently liquid to conclude that forward contracts are readily convertible to cash. If the uranium markets
do become sufficiently liquid in the future and Entergy begins to account for uranium purchase contracts as derivative
instruments, the fair value of these contracts would be accounted for consistent with Entergy’s other derivative
instruments.
Fair Values
The estimated fair values of Entergy’s financial instruments and derivatives are determined using bid prices,
market quotes, and financial modeling. Considerable judgment is required in developing the estimates of fair
value. Therefore, estimates are not necessarily indicative of the amounts that Entergy could realize in a current market
exchange. Gains or losses realized on financial instruments held by regulated businesses may be reflected in future
rates and therefore do not accrue to the benefit or detriment of stockholders. Entergy considers the carrying amounts
of most financial instruments classified as current assets and liabilities to be a reasonable estimate of their fair value
because of the short maturity of these instruments. See Note 16 to the financial statements for further discussion of
fair value.
Impairment of Long-Lived Assets
Entergy periodically reviews long-lived assets held in all of its business segments whenever events or changes
in circumstances indicate that recoverability of these assets is uncertain. Generally, the determination of recoverability
is based on the undiscounted net cash flows expected to result from such operations and assets. Projected net cash
flows depend on the future operating costs associated with the assets, the efficiency and availability of the assets and
generating units, and the future market and price for energy over the remaining life of the assets.
Two nuclear power plants in the Entergy Wholesale Commodities business segment (Indian Point 2 and Indian
Point 3) have an application pending for renewed NRC licenses. Various parties have expressed opposition to renewal
of the licenses. Under federal law, nuclear power plants may continue to operate beyond their original license expiration
dates while their timely filed renewal applications are pending NRC approval. On September 28, 2013, Indian Point
2 reached the expiration date of its original NRC operating license and entered into the period of extended operation
under the timely renewal rule. In December 2015, Indian Point 3 will reach the expiration date of its original NRC
operations license and, similarly, will enter the period of extended operation under the timely renewal rule if its license
is not renewed before then. If the NRC does not renew the operating license for either of these plants, the plant’s
operating life could be shortened, reducing its projected net cash flows and potentially impairing its value as an asset.
69
E-5 Page 17 of 182
Entergy Corporation and Subsidiaries
Notes to Financial Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41
In March 2011 the NRC renewed Vermont Yankee’s operating license for an additional 20 years. The renewed
operating license expires in March 2032. Vermont Yankee operated under a Certificate of Public Good from the State
of Vermont that was scheduled to expire in March 2012, but had an amended petition pending before the Vermont
Public Service Board (VPSB) for a renewed Certificate of Public Good to operate until March 2032.
In June 2013 the VPSB completed hearings on Entergy’s amended petition for a Certificate of Public Good to
continuing operating Vermont Yankee. In August 2013, Entergy announced that it planned to close Vermont Yankee
at the end of 2014 and that same day filed a second amended petition seeking authorization to operate the plant only
until that date. In December 2013, Entergy and Vermont entered into a settlement agreement, with an accompanying
memorandum of understanding that was filed with the VPSB, under which Vermont agreed to support Entergy’s request
to operate Vermont Yankee until the end of 2014. The settlement agreement provided for Entergy to make $10 million
in economic transition payments, $5 million in clean energy development support, and a transitional $5 million payment
to Vermont. The settlement agreement also provided for Entergy to set aside a new $25 million fund to ensure the
Vermont Yankee site is restored after decommissioning. These terms were contingent upon the VPSB issuing by March
31, 2014 a Certificate of Public Good authorizing Vermont Yankee’s operation through 2014, and otherwise conforming
to the terms of the settlement agreement. The settlement agreement also provided for the dismissal or discontinuation
of other litigation between Entergy and Vermont. On March 28, 2014, the VPSB approved the memorandum of
understanding and issued a Certificate of Public Good authorizing Vermont Yankee to operate until December 31,
2014. In May 2014 the VPSB denied a motion that had been filed by one of the intervenors to amend its approval
order. Pursuant to its commitment in the settlement agreement, Entergy Vermont Yankee provided to the Vermont
parties in October 2014, a site assessment study of the costs and tasks of radiological decommissioning, spent nuclear
fuel management, and site restoration of Vermont Yankee. Entergy Vermont Yankee also filed its Post-Shutdown
Decommissioning Activities Report (PSDAR) for Vermont Yankee with the NRC in December 2014.
Because of the uncertainty regarding the continued operation of Vermont Yankee, Entergy tested the
recoverability of the plant and related assets in each quarter since the first quarter 2010 after a bill to approve the
continued operation of Vermont Yankee was defeated in the Vermont legislature. Vermont law at that time required
legislative approval of Vermont Yankee’s continued operation although that law was later invalidated by the U.S. federal
courts as preempted by the Atomic Energy Act. The determination of recoverability is based on the probability-weighted
undiscounted net cash flows expected to be generated by the plant and related assets. Projected net cash flows primarily
depend on the status of the pending legal and state regulatory matters, as well as projections of future revenues and
expenses over the remaining life of the plant. Prior to the first quarter 2012, the probability-weighted undiscounted
net cash flows exceeded the carrying value of the Vermont Yankee plant and related assets. The decline, however, in
the overall energy market and the projected forward prices of power as of March 31, 2012, which are significant inputs
in the determination of net cash flows, resulted in the probability-weighted undiscounted future cash flows being less
than the asset group’s carrying value. Entergy performed a fair value analysis based on the income approach, a
discounted cash flow method, to determine the amount of impairment. The estimated fair value of the plant and related
assets at March 31, 2012 was $162 million, while the carrying value was $517.5 million. Therefore, the assets were
written down to their fair value and an impairment charge of $355.5 million ($223.5 million after-tax) was
recognized. The impairment charge was recorded as a separate line item in Entergy’s consolidated statement of income
for 2012, and is included within the results of the Entergy Wholesale Commodities segment.
The estimate of fair value was based on the price that Entergy would expect to receive in a hypothetical sale
of the Vermont Yankee plant and related assets to a market participant on March 31, 2012. In order to determine this
price, Entergy used significant observable inputs, including quoted forward power and gas prices, where available.
Significant unobservable inputs, such as projected long-term pre-tax operating margins (cash basis), and estimated
weighted average costs of capital were also used in the estimation of fair value. In addition, Entergy made certain
assumptions regarding future tax deductions associated with the plant and related assets. Based on the use of significant
unobservable inputs, the fair value measurement for the entirety of the asset group, and for each type of asset within
the asset group, is classified as Level 3 in the fair value hierarchy discussed in Note 16 to the financial statements.
70
E-5 Page 18 of 182
Entergy Corporation and Subsidiaries
Notes to Financial
Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc.
41
The following table sets forth a description of significant unobservable inputs used in the valuation of the
Vermont Yankee plant and related assets as of March 31, 2012:
Range
Weighted
Average
7.5%-8.0%
6.1%-7.8%
7.8%
7.2%
Significant Unobservable Inputs
Weighted average cost of capital
Long-term pre-tax operating margin (cash basis)
On August 27, 2013, Entergy announced its plan to close and decommission Vermont Yankee at the end of its
fuel cycle at the end of 2014. This decision was approved by the Board in August 2013, although the exact date of
shutdown was not determined. The decision to shut down the plant was primarily due to sustained low natural gas and
wholesale energy prices, the high cost structure of the plant, and lack of a market structure that adequately compensates
merchant nuclear plants for their environmental and fuel diversity benefits in the region in which the plant operates.
As a result of the decision to shut down the plant, Entergy recognized non-cash impairment and other related
charges of $291.5 million ($183.7 million after-tax) during the third quarter 2013 to write down the carrying value of
Vermont Yankee and related assets to their fair values. Entergy performed a fair value analysis based on the income
approach, a discounted cash flow method, to determine the amount of impairment. The estimated fair value of the
plant and related assets was $62 million, while the carrying value was $349 million. The carrying value of $349 million
reflected the effect of a $58 million increase in Vermont Yankee’s estimated decommissioning cost liability and the
related asset retirement cost asset. The increase in the estimated decommissioning cost liability resulted from the
change in expectation regarding the timing of decommissioning cash flows due to the decision to cease operations.
Impairment and other related charges were recorded as a separate line item in Entergy’s consolidated statements of
income for 2013 and this impairment charge is included within the results of the Entergy Wholesale Commodities
segment.
The estimate of fair value was based on the price that Entergy would expect to receive in a hypothetical sale
of the Vermont Yankee plant and related assets to a market participant. In order to determine this price, Entergy used
significant observable inputs, including quoted forward power and gas prices, where available. Significant
unobservable inputs, such as projected long-term pre-tax operating margins (cash basis), and estimated weighted
average costs of capital were also used in the estimation of fair value. In addition, Entergy made certain assumptions
regarding future tax deductions associated with the plant and related assets. Based on the use of significant unobservable
inputs, the fair value measurement for the entirety of the asset group, and for each type of asset within the asset group,
is classified as Level 3 in the fair value hierarchy discussed in Note 16 to the financial statements.
The following table sets forth a description of significant unobservable inputs used in the valuation of the
Vermont Yankee plant and related assets as of July 31, 2013:
Significant Unobservable Inputs
Amount
Weighted average cost of capital
Long-term pre-tax operating margin (cash basis)
7.5%
7.0%
Entergy’s Accounting Policy group, which reports to the Chief Accounting Officer, was primarily responsible for
determining the valuation of the Vermont Yankee plant and related assets, in consultation with external
advisors. Accounting Policy obtained and reviewed information from other Entergy departments with expertise on
the various inputs and assumptions that were necessary to calculate the fair value of the asset group.
As a result of the settlement agreement entered into by Entergy and Vermont regarding the remaining operation
and decommissioning of Vermont Yankee discussed above, Entergy reassessed its assumptions regarding the timing
of decommissioning cash flows for Vermont Yankee. The reassessment resulted in a $27.2 million increase in the
71
E-5 Page 19 of 182
Entergy Corporation and Subsidiaries
Notes to Financial Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41
decommissioning cost liability and a corresponding impairment charge, recorded in December 2013. As part of the
development of the site assessment study and PSDAR, Entergy obtained a revised decommissioning cost study in the
third quarter 2014. The revised estimate, along with reassessment of the assumptions regarding the timing of
decommissioning cash flows, resulted in a $101.6 million increase in the decommissioning cost liability and a
corresponding impairment charge, recorded in September 2014. Impairment charges are recorded as a separate line
item in Entergy’s consolidated statements of income for 2014 and 2013, and this impairment charge is included within
the results of the Entergy Wholesale Commodities segment.
In addition to the $101.6 million impairment charge in September 2014 and depreciation recorded on the
remaining plant balance in 2014, Entergy also recorded charges of $45.8 million related to severance and employee
retention costs in 2014 relating to the shutdown of Vermont Yankee.
Vermont Yankee ceased operation in December 2014. In January 2015, Vermont Yankee completed the
defueling of the reactor and submitted the certification of permanent cessation of operations and permanent removal
of fuel from the reactor vessel to the NRC.
River Bend AFUDC
The River Bend AFUDC gross-up is a regulatory asset that represents the incremental difference imputed by
the LPSC between the AFUDC actually recorded by Entergy Gulf States Louisiana on a net-of-tax basis during the
construction of River Bend and what the AFUDC would have been on a pre-tax basis. The imputed amount was only
calculated on that portion of River Bend that the LPSC allowed in rate base and is being amortized through August
2025.
Reacquired Debt
The premiums and costs associated with reacquired debt of Entergy’s Utility operating companies and System
Energy (except that portion allocable to the deregulated operations of Entergy Gulf States Louisiana) are included in
regulatory assets and are being amortized over the life of the related new issuances, or over the life of the original debt
issuance if the debt is not refinanced, in accordance with ratemaking treatment.
Taxes Imposed on Revenue-Producing Transactions
Governmental authorities assess taxes that are both imposed on and concurrent with a specific revenueproducing transaction between a seller and a customer, including, but not limited to, sales, use, value added, and some
excise taxes. Entergy presents these taxes on a net basis, excluding them from revenues, unless required to report them
differently by a regulatory authority.
Presentation of Preferred Stock without Sinking Fund
Accounting standards regarding non-controlling interests and the classification and measurement of redeemable
securities require the classification of preferred securities between liabilities and shareholders’ equity on the balance
sheet if the holders of those securities have protective rights that allow them to gain control of the board of directors
in certain circumstances. These rights would have the effect of giving the holders the ability to potentially redeem
their securities, even if the likelihood of occurrence of these circumstances is considered remote. The Entergy Arkansas,
Entergy Mississippi, and Entergy New Orleans articles of incorporation provide, generally, that the holders of each
company’s preferred securities may elect a majority of the respective company’s board of directors if dividends are
not paid for a year, until such time as the dividends in arrears are paid. Therefore, Entergy Arkansas, Entergy Mississippi,
and Entergy New Orleans present their preferred securities outstanding between liabilities and shareholders’ equity on
the balance sheet. Entergy Gulf States Louisiana and Entergy Louisiana, both organized as limited liability companies,
have outstanding preferred securities with similar protective rights with respect to unpaid dividends, but provide for
72
E-5 Page 20 of 182
Entergy Corporation and Subsidiaries
Notes to Financial
Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc.
41
the election of board members that would not constitute a majority of the board; and their preferred securities are
therefore classified for all periods presented as a component of members’ equity.
The outstanding preferred securities of Entergy Arkansas, Entergy Mississippi, Entergy New Orleans, and
Entergy Finance Holding (an Entergy Wholesale Commodities subsidiary), whose preferred holders also have protective
rights, are similarly presented between liabilities and equity on Entergy’s consolidated balance sheets and the
outstanding preferred securities of Entergy Gulf States Louisiana and Entergy Louisiana are presented within total
equity in Entergy’s consolidated balance sheets. The preferred dividends or distributions paid by all subsidiaries are
reflected for all periods presented outside of consolidated net income.
New Accounting Pronouncements
The accounting standard-setting process, including projects between the FASB and the International
Accounting Standards Board (IASB) to converge U.S. GAAP and International Financial Reporting Standards, is
ongoing and the FASB and the IASB are each currently working on several projects. Final pronouncements that result
from these projects could have a material effect on Entergy’s future net income, financial position, or cash flows.
In April 2014 the FASB issued ASU No. 2014-08, “Presentation of Financial Statements (Topic 205) and
Property Plant, and Equipment (Topic 360): Reporting Discontinued Operations and Disclosures of Disposals of
Components of an Entity” which changes the requirements for reporting discontinued operations. The ASU states that
a disposal of a component of an entity or a group of components of an entity is required to be reported in discontinued
operations if the disposal represents a strategic shift that has or will have a major effect on an entity’s operations and
financial results when the component of an entity or group of components of an entity meets the criteria to be classified
as held for sale, is disposed of by sale, or is disposed of other than by sale. The amendments in this ASU also require
additional disclosures about discontinued operations. ASU 2014-08 is effective for Entergy for the first quarter 2015.
Entergy does not currently expect ASU 2014-08 to affect materially its results of operations, financial position, or cash
flows.
In May 2014 the FASB issued ASU No. 2014-09, “Revenue from Contracts with Customers (Topic 606).”
The ASU’s core principle is that “an entity should recognize revenue to depict the transfer of promised goods or services
to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for
those goods or services.” The ASU details a five-step model that should be followed to achieve the core principle.
ASU 2014-09 is effective for Entergy for the first quarter 2017. Entergy does not expect ASU 2014-09 to affect
materially its results of operations, financial position, or cash flows.
In November 2014 the FASB issued ASU No. 2014-16, “Derivatives and Hedging (Topic 815): Determining
Whether the Host Contract in a Hybrid Financial Instrument Issued in the Form of a Share Is More Akin to Debt or to
Equity.” The ASU states that for hybrid financial instruments issued in the form of a share, an entity should determine
the nature of the host contract by considering all stated and implied substantive terms and features of the hybrid financial
instrument, weighing each term and feature on the basis of relevant facts and circumstances. ASU 2014-16 is effective
for Entergy for the first quarter 2016. Entergy does not expect ASU 2014-16 to affect materially its results of operations,
financial position, or cash flows.
73
E-5 Page 21 of 182
Entergy Corporation and Subsidiaries
Notes to Financial Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41
NOTE 2. RATE AND REGULATORY MATTERS (Entergy Corporation, Entergy Arkansas, Entergy Gulf
States Louisiana, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System
Energy)
Regulatory Assets and Regulatory Liabilities
Regulatory assets represent probable future revenues associated with costs that Entergy expects to recover
from customers through the regulatory ratemaking process under which the Utility business operates. Regulatory
liabilities represent probable future reductions in revenues associated with amounts that Entergy expects to benefit
customers through the regulatory ratemaking process under which the Utility business operates. In addition to the
regulatory assets and liabilities that are specifically disclosed on the face of the balance sheets, the tables below provide
detail of “Other regulatory assets” and “Other regulatory liabilities” that are included on Entergy’s and the Registrant
Subsidiaries’ balance sheets as of December 31, 2014 and 2013:
Other Regulatory Assets
Entergy
2014
2013
(In Millions)
Pension & postretirement costs (Note 11 – Qualified Pension Plans, Other
Postretirement Benefits, and Non-Qualified Pension Plans) (b)
Storm damage costs, including hurricane costs - recovered through securitization
and retail rates (Note 2 – Storm Cost Recovery Filings with Retail Regulators)
Asset retirement obligation - recovery dependent upon timing of decommissioning
of nuclear units or dismantlement of non-nuclear power plants (Note 9) (b)
Removal costs - recovered through depreciation rates (Note 9) (b)
Little Gypsy costs – recovered through securitization (Note 5 – Entergy Louisiana
Securitization Bonds - Little Gypsy)
Under-recovered retail rate revenues - recovered through rate riders when rates
are redetermined periodically
Unamortized loss on reacquired debt - recovered over term of debt
MISO implementation costs - recovery through retail rate riders (Note 2 - Retail
Rate Proceedings)
Transition to competition costs - recovered over a 15-year period through
February 2021
New nuclear generation development costs (Note 2 - New Nuclear Generation
Development Costs) (c)
Human capital management costs - recovery through retail rate mechanisms
(Note 2 - Retail Rate Proceedings)
Other
Entergy Total
74
$2,798.8
$1,723.1
736.2
786.8
513.8
245.1
447.6
188.9
139.2
160.6
79.6
76.2
77.7
83.0
69.6
74.7
66.2
74.4
58.4
115.2
42.3
143.2
$4,968.6
45.0
116.4
$3,893.4
E-5 Page 22 of 182
Entergy Corporation and Subsidiaries
Notes to Financial
Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc.
41
Entergy Arkansas
2014
2013
(In Millions)
Pension & postretirement costs (Note 11 – Qualified Pension Plans, Other
Postretirement Benefits, and Non-Qualified Pension Plans) (b)
Asset retirement obligation - recovery dependent upon timing of decommissioning
of nuclear units or dismantlement of non-nuclear power plants (Note 9) (b)
Storm damage costs - recovered either through securitization or retail rates (Note 2
- Storm Cost Recovery Filings with Retail Regulators)
Removal costs - recovered through depreciation rates (Note 9) (b)
Unamortized loss on reacquired debt - recovered over term of debt
MISO implementation costs - recovery through retail rates through 2018 (Note 2 Retail Rate Proceedings) (c)
Under-recovered retail rate revenues - recovered through rate riders when rates
are redetermined periodically
Human capital management costs - recovery through retail rates through June
2017 (Note 2 - Retail Rate Proceedings) (c)
Incremental ice storm costs - recovered through 2032
Other
Entergy Arkansas Total
$838.2
$517.1
254.8
225.9
125.6
59.0
26.2
115.2
18.6
28.8
25.1
30.9
23.3
36.1
17.3
9.0
12.8
$1,391.3
22.0
9.5
10.3
$1,014.4
Entergy Gulf States Louisiana
2014
2013
(In Millions)
Pension & postretirement costs (Note 11 – Qualified Pension Plans and NonQualified Pension Plans) (b)
New nuclear generation development costs - recovery through formula rate plan
beginning December 2014 through November 2022 (Note 2 - New Nuclear
Generation Development Costs) (c)
Spindletop gas storage facility - recovery period through December 2032 (a)
River Bend AFUDC - recovered through August 2025 (Note 1 – River Bend
AFUDC)
MISO implementation costs - recovery through the MISO cost recovery
mechanism beginning December 2014 through November 2017 (Note 2 - Retail
Rate Proceedings)
Human capital management costs - recovery through formula rate plan beginning
December 2014 through November 2017 (Note 2 - Retail Rate Proceedings)
Under-recovered retail rate revenues - recovered through rate riders when rates
are redetermined periodically
Asset retirement obligation - recovery dependent upon timing of decommissioning
of nuclear units or dismantlement of non-nuclear power plants (Note 9) (b)
Gas hedging costs - recovered through fuel rates upon settlement
(Note 16 - Derivatives)
Unamortized loss on reacquired debt - recovered over term of debt
Other
Entergy Gulf States Louisiana Total
75
$286.8
$194.2
29.2
26.2
29.5
27.8
18.6
20.5
15.7
15.3
11.2
10.0
11.1
3.0
10.8
11.0
8.2
6.8
1.8
$426.4
—
8.3
1.9
$321.5
E-5 Page 23 of 182
Entergy Corporation and Subsidiaries
Notes to Financial Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41
Entergy Louisiana
2014
2013
(In Millions)
Pension & postretirement costs (Note 11 – Qualified Pension Plans and NonQualified Pension Plans) (b)
Asset Retirement Obligation - recovery dependent upon timing of
decommissioning of nuclear units or dismantlement of non-nuclear power plants
(Note 9) (b)
Little Gypsy costs – recovered through securitization (Note 5 – Entergy Louisiana
Securitization Bonds - Little Gypsy)
New nuclear generation development costs - recovery through formula rate plan
beginning December 2014 through November 2022 (Note 2 - New Nuclear
Generation Development Costs) (c)
MISO implementation costs - recovery through the MISO cost recovery
mechanism beginning December 2014 through November 2017 (Note 2 - Retail
Rate Proceedings)
Unamortized loss on reacquired debt - recovered over term of debt
Human capital management costs - recovery through formula rate plan beginning
December 2014 through November 2017 (Note 2 - Retail Rate Proceedings)
Storm damage costs, including hurricane costs - recovered through retail rates
(Note 2 - Storm Cost Recovery Filings with Retail Regulators)
Other
Entergy Louisiana Total
$487.2
$318.4
156.7
139.2
139.2
160.6
29.2
29.5
21.4
14.3
20.8
15.2
13.8
13.0
13.7
38.7
$914.2
3.4
15.4
$715.5
Entergy Mississippi
2014
2013
(In Millions)
Pension & postretirement costs (Note 11 – Qualified Pension Plans, Other
Postretirement Benefits, and Non-Qualified Pension Plans) (b)
Removal costs - recovered through depreciation rates (Note 9) (b)
Under-recovered retail rate revenues - recovered through rate riders when rates
are redetermined periodically
Unamortized loss on reacquired debt - recovered over term of debt
Asset retirement obligation - recovery dependent upon timing of dismantlement of
non-nuclear power plants (Note 9) (b)
Baxter Wilson outage costs - recovered through retail rates over two years
beginning February 2015 (Note 8 - Baxter Wilson Plant Event)
MISO implementation costs - recovery through retail rate riders (Note 2 – Retail
Rate Proceedings)
New nuclear generation development costs (Note 2 - New Nuclear Generation
Development Costs)
Other
Entergy Mississippi Total
76
$224.3
76.3
$135.3
64.3
28.7
8.2
39.2
8.9
6.3
5.9
6.0
—
4.0
4.2
—
10.9
$364.7
56.2
4.5
$318.5
E-5 Page 24 of 182
Entergy Corporation and Subsidiaries
Notes to Financial
Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc.
41
Entergy New Orleans
2014
2013
(In Millions)
Pension & postretirement costs (Note 11 – Qualified Pension Plans, Other
Postretirement Benefits, and Non-Qualified Pension Plans) (b)
Removal costs - recovered through depreciation rates (Note 9) (b)
Michoud plant maintenance – recovered over a 7-year period through September
2018
Storm damage costs, including hurricane costs - recovered through retail rates
and securitization (Note 2 - Storm Cost Recovery Filings with Retail Regulators)
Asset retirement obligation - recovery dependent upon timing of dismantlement of
non-nuclear power plants (Note 9) (b)
Unamortized loss on reacquired debt - recovered over term of debt
Other
Entergy New Orleans Total
$115.8
35.2
$76.8
34.9
7.2
9.1
5.0
4.6
3.8
1.8
6.8
$175.6
3.7
2.0
6.1
$137.2
Entergy Texas
2014
2013
(In Millions)
Storm damage costs, including hurricane costs - recovered through securitization
and retail rates (Note 2 - Storm Cost Recovery Filings with Retail Regulators)
Pension & postretirement costs (Note 11 – Qualified Pension Plans, Other
Postretirement Benefits, and Non-Qualified Pension Plans) (b)
Transition to competition costs - recovered over a 15-year period through
February 2021
Removal costs - recovered through depreciation rates (Note 9) (b)
Unamortized loss on reacquired debt - recovered over term of debt
Rate case costs - recovered through retail rates (c)
Other
Entergy Texas Total
$591.7
$663.6
217.0
143.0
66.2
18.9
10.5
8.4
9.4
$922.1
74.4
15.1
7.7
10.8
4.6
$919.2
System Energy
2014
2013
(In Millions)
Pension & postretirement costs (Note 11 – Qualified Pension Plans and Other
Postretirement Benefits) (b)
Asset retirement obligation - recovery dependent upon timing of decommissioning
(Note 9) (b)
Removal costs - recovered through depreciation rates (Note 9) (b)
Unamortized loss on reacquired debt - recovered over term of debt
System Energy Total
(a)
$191.0
$132.9
80.4
55.7
8.5
$335.6
60.8
56.0
12.0
$261.7
The jurisdictional split order assigned the regulatory asset to Entergy Texas. The regulatory asset, however,
is being recovered and amortized at Entergy Gulf States Louisiana. As a result, a billing occurs monthly over
the same term as the recovery and receipts will be submitted to Entergy Texas. Entergy Texas has recorded a
receivable from Entergy Gulf States Louisiana and Entergy Gulf States Louisiana has recorded a corresponding
payable.
77
E-5 Page 25 of 182
Entergy Corporation and Subsidiaries
Notes to Financial Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41
(b)
(c)
Does not earn a return on investment, but is offset by related liabilities.
Does not earn a return on investment.
Other Regulatory Liabilities
Entergy
2014
Unrealized gains on nuclear decommissioning trust funds (Note 17) (a)
Vidalia purchased power agreement (Note 8)
Louisiana Act 55 financing savings obligation (Note 2)
Removal costs - returned to customers through depreciation rates (Note 9) (a)
Grand Gulf sale-leaseback - (Note 10 - Sale and Leaseback Transactions)
Entergy Mississippi’s accumulated accelerated Grand Gulf amortization amortized and credited through the UPSA
Entergy Arkansas’s accumulated accelerated Grand Gulf amortization - will
be returned to customers when approved by the APSC and FERC
Asset retirement obligation - will be returned to customers dependent upon timing
of decommissioning (Note 9) (a)
Other
Entergy Total
2013
$656.7
242.8
156.0
82.7
79.5
$529.6
263.1
156.0
72.3
92.3
53.6
60.7
44.4
44.4
27.7
40.2
$1,383.6
31.5
46.1
$1,296.0
Entergy Arkansas
Unrealized gains on nuclear decommissioning trust funds (Note 17) (a)
Deferred capacity acquisition cost recovery - returned to customers through rate
riders when rates are redetermined periodically
Other
Entergy Arkansas Total
2014
2013
(In Millions)
$254.0
$214.1
—
—
$254.0
4.7
0.6
$219.4
Entergy Gulf States Louisiana
Unrealized gains on nuclear decommissioning trust funds (Note 17) (a)
Removal costs - returned to customers through depreciation rates (Note 9) (a)
Asset retirement obligation - will be returned to customers dependent upon timing
of decommissioning (Note 9) (a)
Louisiana Act 55 financing savings obligation (Note 2)
Gas hedging costs - returned to customers through fuel rates (Note 16 Derivatives)
Other
Entergy Gulf States Louisiana Total
78
2014
2013
(In Millions)
$85.9
$64.1
36.9
35.3
27.7
25.5
31.5
25.5
—
0.3
$176.3
2.2
0.8
$159.4
E-5 Page 26 of 182
Entergy Corporation and Subsidiaries
Notes to Financial
Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc.
41
Entergy Louisiana
Vidalia purchased power agreement (Note 8)
Louisiana Act 55 financing savings obligation (Note 2)
Unrealized gains on nuclear decommissioning trust funds (Note 17) (a)
Removal costs - returned to customers through depreciation rates (Note 9) (a)
Other
Entergy Louisiana Total
2014
2013
(In Millions)
$242.8
$263.1
130.5
130.5
123.2
98.9
45.7
37.0
3.9
3.7
$546.1
$533.2
Entergy Texas
2014
2013
(In Millions)
Transition to competition costs - returned to customers through rate riders when
rates are redetermined periodically
Line loss adjustment - returned to customers through fuel rates
Entergy Texas Total
$5.1
—
$5.1
$4.2
1.0
$5.2
System Energy
Unrealized gains on nuclear decommissioning trust funds (Note 17) (a)
Grand Gulf sale-leaseback - (Note 10 - Sale and Leaseback Transactions)
Entergy Mississippi’s accumulated accelerated Grand Gulf amortization amortized and credited through the UPSA
Entergy Arkansas’s accumulated accelerated Grand Gulf amortization - will
be returned to customers when approved by the APSC and FERC
System Energy Total
(a)
2014
2013
(In Millions)
$193.6
$152.4
79.5
92.3
53.6
60.7
44.4
$371.1
44.4
$349.8
Offset by related asset.
79
E-5 Page 27 of 182
Entergy Corporation and Subsidiaries
Notes to Financial Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41
Fuel and purchased power cost recovery
Entergy Arkansas, Entergy Gulf States Louisiana, Entergy Louisiana, Entergy Mississippi, Entergy New
Orleans, and Entergy Texas are allowed to recover fuel and purchased power costs through fuel mechanisms included
in electric and gas rates that are recorded as fuel cost recovery revenues. The difference between revenues collected
and the current fuel and purchased power costs is generally recorded as “Deferred fuel costs” on the Utility operating
companies’ financial statements. The table below shows the amount of deferred fuel costs as of December 31, 2014
and 2013 that Entergy expects to recover (or return to customers) through fuel mechanisms, subject to subsequent
regulatory review.
Entergy Arkansas (a)
Entergy Gulf States Louisiana (b)
Entergy Louisiana (b)
Entergy Mississippi
Entergy New Orleans (b)
Entergy Texas
(a)
(b)
2014
2013
(In Millions)
$209.2
$68.7
$89.5
$109.7
$17.6
$37.6
($2.2)
$38.1
($24.3)
($19.1)
$11.9
($4.1)
2014 includes $65.9 million for Entergy Arkansas of fuel, purchased power, and capacity costs, which do not
currently earn a return on investment and whose recovery periods are indeterminate but are expected to be
recovered over a period greater than twelve months.
2014 and 2013 include $100.1 million for Entergy Gulf States Louisiana, $68 million for Entergy Louisiana,
and $4.1 million for Entergy New Orleans of fuel, purchased power, and capacity costs, which do not currently
earn a return on investment and whose recovery periods are indeterminate but are expected to be recovered
over a period greater than twelve months.
Entergy Arkansas
Production Cost Allocation Rider
The APSC approved a production cost allocation rider for recovery from customers of the retail portion of the
costs allocated to Entergy Arkansas as a result of the System Agreement proceedings, which are discussed in the
“System Agreement Cost Equalization Proceedings” section below. These costs cause an increase in Entergy
Arkansas’s deferred fuel cost balance because Entergy Arkansas pays the costs over seven months but collects them
from customers over twelve months.
In May 2014, Entergy Arkansas filed its annual redetermination of the production cost allocation rider to
recover the $3 million unrecovered retail balance as of December 31, 2013 and the $67.8 million System Agreement
bandwidth remedy payment made in May 2014 as a result of the compliance filing pursuant to the FERC’s February
2014 orders related to the bandwidth payments/receipts for the June - December 2005 period. In June 2014 the APSC
suspended the annual redetermination of the production cost allocation rider and scheduled a hearing in September
2014. Upon a joint motion of the parties, the APSC canceled the September 2014 hearing and in January 2015 the
APSC issued an order approving Entergy Arkansas’s request for recovery of the $3 million under-recovered amount
based on the true-up of the production cost allocation rider and the $67.8 million May 2014 System Agreement
bandwidth remedy payment subject to refund with interest, with recovery of these payments concluding with the last
billing cycle in December 2015. The APSC also found that Entergy Arkansas is entitled to carrying charges pursuant
to the current terms of the production cost allocation rider. Entergy Arkansas made its compliance filing pursuant to
the order in January 2015 and the APSC issued its approval order, also in January 2015. The redetermined rate went
into effect the first billing cycle of February 2015.
80
E-5 Page 28 of 182
Entergy Corporation and Subsidiaries
Notes to Financial
Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc.
41
Energy Cost Recovery Rider
Entergy Arkansas’s retail rates include an energy cost recovery rider to recover fuel and purchased energy
costs in monthly customer bills. The rider utilizes the prior calendar-year energy costs and projected energy sales for
the twelve-month period commencing on April 1 of each year to develop an energy cost rate, which is redetermined
annually and includes a true-up adjustment reflecting the over- or under-recovery, including carrying charges, of the
energy costs for the prior calendar year. The energy cost recovery rider tariff also allows an interim rate request
depending upon the level of over- or under-recovery of fuel and purchased energy costs.
In October 2005 the APSC initiated an investigation into Entergy Arkansas’s interim energy cost recovery
rate. The investigation focused on Entergy Arkansas’s 1) gas contracting, portfolio, and hedging practices; 2) wholesale
purchases during the period; 3) management of the coal inventory at its coal generation plants; and 4) response to the
contractual failure of the railroads to provide coal deliveries. In March 2006 the APSC extended its investigation to
cover the costs included in Entergy Arkansas’s March 2006 annual energy cost rate filing, and a hearing was held in
the APSC investigation in October 2006.
In January 2007 the APSC issued an order in its review of the energy cost rate. The APSC found that Entergy
Arkansas failed to maintain an adequate coal inventory level going into the summer of 2005 and that Entergy Arkansas
should be responsible for any incremental energy costs that resulted from two outages caused by employee and contractor
error. The coal plant generation curtailments were caused by railroad delivery problems and Entergy Arkansas has
since resolved litigation with the railroad regarding the delivery problems. The APSC staff was directed to perform
an analysis with Entergy Arkansas’s assistance to determine the additional fuel and purchased energy costs associated
with these findings and file the analysis within sixty days of the order. After a final determination of the costs is made
by the APSC, Entergy Arkansas will be directed to refund that amount with interest to its customers as a credit on the
energy cost recovery rider. Entergy Arkansas requested rehearing of the order.
In February 2010 the APSC denied Entergy Arkansas’s request for rehearing, and held a hearing in September
2010 to determine the amount of damages, if any, that should be assessed against Entergy Arkansas. A decision is
pending. Entergy Arkansas expects the amount of damages, if any, to have an immaterial effect on its results of
operations, financial position, or cash flows.
The APSC also established a separate docket to consider the resolved railroad litigation, and in February 2010
it established a procedural schedule that concluded with testimony through September 2010. The testimony has been
filed, and the APSC will decide the case based on the record in the proceeding.
In January 2014, Entergy Arkansas filed a motion with the APSC relating to its redetermination of its energy
cost rate to be filed in March 2014. In that motion, Entergy Arkansas requested that the APSC authorize Entergy
Arkansas to exclude $65.9 million of deferred fuel and purchased energy costs incurred in 2013 from the redetermination
of its 2014 energy cost rate. The $65.9 million is an estimate of the incremental fuel and replacement energy costs
that Entergy Arkansas incurred as a result of the ANO stator incident. Entergy Arkansas requested that the APSC
authorize Entergy Arkansas to retain that amount in its deferred fuel balance, with recovery to be reviewed in a later
period after more information is available regarding various claims associated with the ANO stator incident. The APSC
approved Entergy Arkansas’s request in February 2014. See the “ANO Damage, Outage, and NRC Reviews” section
in Note 8 to the financial statements for further discussion of the ANO stator incident.
Entergy Gulf States Louisiana and Entergy Louisiana
Entergy Gulf States Louisiana and Entergy Louisiana recover electric fuel and purchased power costs for the
billing month based upon the level of such costs incurred two months prior to the billing month. Entergy Gulf States
Louisiana’s purchased gas adjustments include estimates for the billing month adjusted by a surcharge or credit that
arises from an annual reconciliation of fuel costs incurred with fuel cost revenues billed to customers, including carrying
charges.
81
E-5 Page 29 of 182
Entergy Corporation and Subsidiaries
Notes to Financial Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41
In April 2010 the LPSC authorized its staff to initiate an audit of Entergy Louisiana’s fuel adjustment clause
filings. The audit includes a review of the reasonableness of charges flowed through the fuel adjustment clause by
Entergy Louisiana for the period from 2005 through 2009. The LPSC Staff issued its audit report in January 2013. The
LPSC staff recommended that Entergy Louisiana refund approximately $1.9 million, plus interest, to customers and
realign the recovery of approximately $1 million from Entergy Louisiana’s fuel adjustment clause to base rates. The
recommended refund was made by Entergy Louisiana in May 2013 in the form of a credit to customers through its
fuel adjustment clause filing. Two parties intervened in the proceeding. A procedural schedule was established for
the identification of issues by the intervenors and for Entergy Louisiana to submit comments regarding the LPSC Staff
report and any issues raised by intervenors. One intervenor is seeking further proceedings regarding certain issues it
raised in its comments on the LPSC Staff report. Entergy Louisiana has filed responses to both the LPSC Staff report
and the issues raised by the intervenor. As required by the procedural schedule, a joint status report was submitted in
October 2013 by the parties. A status conference was held in December 2013. Discovery is in progress, but a procedural
schedule has not been established.
In December 2011 the LPSC authorized its staff to initiate another proceeding to audit the fuel adjustment
clause filings of Entergy Gulf States Louisiana and its affiliates. The audit includes a review of the reasonableness of
charges flowed by Entergy Gulf States Louisiana through its fuel adjustment clause for the period 2005 through
2009. Discovery is in progress, but a procedural schedule has not been established.
In July 2014 the LPSC authorized its staff to initiate an audit of Entergy Gulf States Louisiana’s fuel adjustment
clause filings. The audit includes a review of the reasonableness of charges flowed by Entergy Gulf States Louisiana
through its fuel adjustment clause for the period from 2010 through 2013. Discovery has yet to commence.
In July 2014 the LPSC authorized its staff to initiate an audit of Entergy Louisiana’s fuel adjustment clause
filings. The audit includes a review of the reasonableness of charges flowed by Entergy Louisiana through its fuel
adjustment clause for the period from 2010 through 2013. Discovery has yet to commence.
Entergy Mississippi
Entergy Mississippi’s rate schedules include an energy cost recovery rider that is adjusted annually to reflect
accumulated over- or under-recoveries. Entergy Mississippi’s fuel cost recoveries are subject to annual audits
conducted pursuant to the authority of the MPSC.
Entergy Mississippi had a deferred fuel balance of $60.4 million as of March 31, 2014. In May 2014, Entergy
Mississippi filed for an interim adjustment under its energy cost recovery rider. The interim adjustment proposed a
net energy cost factor designed to collect over a six-month period the under-recovered deferred fuel balance as of
March 31, 2014 and also reflected a natural gas price of $4.50 per MMBtu. In May 2014, Entergy Mississippi and the
Public Utilities Staff entered into a joint stipulation in which Entergy Mississippi agreed to a revised net energy cost
factor that reflected the proposed interim adjustment with a reduction in costs recovered through the energy cost
recovery rider associated with the suspension of the DOE nuclear waste storage fee. In June 2014 the MPSC approved
the joint stipulation and allowed Entergy Mississippi’s interim adjustment. In November 2014, Entergy Mississippi
filed its annual redetermination of the annual factor to be applied under the energy cost recovery rider. Due to lower
gas prices and a lower deferred fuel balance, the redetermined annual factor was a decrease from the revised interim
net energy cost factor. In January 2015 the MPSC approved the redetermined annual factor effective January 30, 2015.
Mississippi Attorney General Complaint
The Mississippi attorney general filed a complaint in state court in December 2008 against Entergy Corporation,
Entergy Mississippi, Entergy Services, and Entergy Power alleging, among other things, violations of Mississippi
statutes, fraud, and breach of good faith and fair dealing, and requesting an accounting and restitution. The complaint
is wide ranging and relates to tariffs and procedures under which Entergy Mississippi purchases power not generated
in Mississippi to meet electricity demand. Entergy believes the complaint is unfounded. In December 2008 the
82
E-5 Page 30 of 182
Entergy Corporation and Subsidiaries
Notes to Financial
Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc.
41
defendant Entergy companies removed the attorney general’s lawsuit to U.S. District Court in Jackson, Mississippi. The
Mississippi attorney general moved to remand the matter to state court. In August 2012 the District Court issued an
opinion denying the Attorney General’s motion for remand, finding that the District Court has subject matter jurisdiction
under the Class Action Fairness Act.
The defendant Entergy companies answered the complaint and filed a counterclaim for relief based upon the
Mississippi Public Utilities Act and the Federal Power Act. In May 2009 the defendant Entergy companies filed a
motion for judgment on the pleadings asserting grounds of federal preemption, the exclusive jurisdiction of the MPSC,
and factual errors in the attorney general’s complaint. In September 2012 the District Court heard oral argument on
Entergy’s motion for judgment on the pleadings. The District Court’s ruling on the motion for judgment on the pleadings
is pending.
In January 2014 the U.S. Supreme Court issued a decision in which it held that cases brought by attorneys
general as the sole plaintiff to enforce state laws were not subject to the federal law that allowed federal courts to hear
those cases as “mass action” lawsuits. One day later the Attorney General renewed its motion to remand the Entergy
case back to state court, citing the U.S. Supreme Court’s decision. The defendant Entergy companies have responded
to that motion and the District Court held oral argument on the motion to remand in February 2014. Entergy also has
asserted federal question jurisdiction as a basis for the district court having jurisdiction and also has pending the motion
for judgment on the pleadings.
Entergy New Orleans
Entergy New Orleans’s electric rate schedules include a fuel adjustment tariff designed to reflect no more than
targeted fuel and purchased power costs, adjusted by a surcharge or credit for deferred fuel expense arising from the
monthly reconciliation of actual fuel and purchased power costs incurred with fuel cost revenues billed to customers,
including carrying charges.
Entergy New Orleans’s gas rate schedules include a purchased gas adjustment to reflect estimated gas costs
for the billing month, adjusted by a surcharge or credit similar to that included in the electric fuel adjustment clause,
including carrying charges.
Entergy Texas
Entergy Texas’s rate schedules include a fixed fuel factor to recover fuel and purchased power costs, including
interest, not recovered in base rates. Semi-annual revisions of the fixed fuel factor are made in March and September
based on the market price of natural gas and changes in fuel mix. The amounts collected under Entergy Texas’s fixed
fuel factor and any interim surcharge or refund are subject to fuel reconciliation proceedings before the PUCT.
In December 2011, Entergy Texas filed with the PUCT a request to refund approximately $43 million, including
interest, of fuel cost recovery over-collections through October 2011. Entergy Texas and the parties to the proceeding
reached an agreement that Entergy Texas would refund $67 million, including interest and additional over-recoveries
through December 2011, over a three-month period. Entergy Texas and the parties requested that interim rates consistent
with the settlement be approved effective with the March 2012 billing month, and the PUCT approved the application
in March 2012. Entergy Texas completed this refund to customers in May 2012.
In October 2012, Entergy Texas filed with the PUCT a request to refund approximately $78 million, including
interest, of fuel cost recovery over-collections through September 2012. Entergy Texas requested that the refund be
implemented over a six-month period effective with the January 2013 billing month. Entergy Texas and the parties to
the proceeding reached an agreement that Entergy Texas would refund $84 million, including interest and additional
over-recoveries through October 2012, to most customers over a three-month period beginning January 2013. The
PUCT approved the stipulation in January 2013. Entergy Texas completed this refund to customers in March 2013.
83
E-5 Page 31 of 182
Entergy Corporation and Subsidiaries
Notes to Financial Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41
In July 2012, Entergy Texas filed with the PUCT an application to credit its customers approximately $37.5
million, including interest, resulting from the FERC’s October 2011 order in the System Agreement rough production
cost equalization proceeding which is discussed below in “System Agreement Cost Equalization Proceedings.” In
September 2012 the parties submitted a stipulation resolving the proceeding. The stipulation provided that most Entergy
Texas customers would be credited over a four-month period beginning October 2012. The credits were initiated with
the October 2012 billing month on an interim basis, and the PUCT subsequently approved the stipulation, also in
October 2012.
In August 2014, Entergy Texas filed an application seeking PUCT approval to implement an interim fuel refund
of approximately $24.6 million for over-collected fuel costs incurred during the months of November 2012 through
April 2014. This refund resulted from (i) applying $48.6 million in bandwidth remedy payments that Entergy Texas
received in May 2014 related to the June - December 2005 period to Entergy Texas’s $8.7 million under-recovered
fuel balance as of April 30, 2014 and (ii) netting that fuel balance against the $15.3 million bandwidth remedy payment
that Entergy Texas made related to calendar year 2013 production costs. Also in August 2014, Entergy Texas filed an
unopposed motion for interim rates to implement these refunds for most customers over a two-month period
commencing with September 2014. The PUCT issued its order approving the interim relief in August 2014 and Entergy
Texas completed the refunds in October 2014. Parties intervened in this matter. All parties agreed that this case should
be bifurcated such that the interim refunds would become final in a separate docket. The current docket would remain
in place to potentially address additional rough production cost equalization-related matters that are not part of the
interim refunds discussed above. In January 2015, Entergy Texas filed a request for this severance and final approval
of the interim refund. Both applications are pending.
At the PUCT’s April 2013 open meeting, the PUCT Commissioners discussed their view that a purchased
power capacity rider was good public policy. The PUCT issued an order in May 2013 adopting the rule allowing for
a purchased power capacity rider, subject to an offsetting adjustment for load growth. The rule, as adopted, also includes
a process for obtaining pre-approval by the PUCT of purchased power agreements. Entergy Texas has not exercised
the option to recover its capacity costs under the new rider mechanism, but will continue to evaluate the benefits of
utilizing the new rider to recover future capacity costs.
Retail Rate Proceedings
Filings with the APSC (Entergy Arkansas)
Retail Rates
In March 2013, Entergy Arkansas filed with the APSC for a general change in rates, charges, and tariffs. The
filing assumed Entergy Arkansas’s transition to MISO in December 2013, and requested a rate increase of $174 million,
including $49 million of revenue being transferred from collection in riders to base rates. The filing also proposed a
new transmission rider and a capacity cost recovery rider. The filing requested a 10.4% return on common equity. In
September 2013, Entergy Arkansas filed testimony reflecting an updated rate increase request of $145 million, with
no change to its requested return on common equity of 10.4%. Hearings in the proceeding began in October 2013,
and in December 2013 the APSC issued an order. The order authorized a base rate increase of $81 million and included
an authorized return on common equity of 9.3%. The order allows Entergy Arkansas to amortize its human capital
management costs over a three-and-a-half year period, but also orders Entergy Arkansas to file a detailed report of the
Arkansas-specific costs, savings and final payroll changes upon conclusion of the human capital management strategic
imperative. The detailed report was subsequently filed in February 2015. The substance of the report will be addressed
in Entergy Arkansas’s next base rate filing. New rates under the January 2014 order were implemented in the first
billing cycle of March 2014 and were effective as of January 2014. Additionally, in January 2014, Entergy Arkansas
filed a petition for rehearing or clarification of several aspects of the APSC’s order, including the 9.3% authorized
return on common equity. In February 2014 the APSC granted Entergy Arkansas’s petition for the purpose of considering
the additional evidence identified by Entergy Arkansas. In August 2014 the APSC issued an order amending certain
aspects of the original order, including providing for a 9.5% authorized return on common equity. Pursuant to the
84
E-5 Page 32 of 182
Entergy Corporation and Subsidiaries
Notes to Financial
Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc.
41
August 2014 order, revised rates are effective for all bills rendered after December 31, 2013 and were implemented in
the first billing cycle of October 2014.
On January 30, 2015, Entergy Arkansas filed with the APSC a notice of intent to file a rate case within 60 to
90 days.
Filings with the LPSC
Retail Rates - Electric
(Entergy Gulf States Louisiana)
In November 2011 the LPSC approved a one-year extension of Entergy Gulf States Louisiana’s formula rate
plan. In May 2012, Entergy Gulf States Louisiana made its formula rate plan filing with the LPSC for the 2011 test
year. The filing reflected an 11.94% earned return on common equity, which was above the earnings bandwidth and
indicated a $6.5 million cost of service rate decrease was necessary under the formula rate plan. The filing also reflected
a $22.9 million rate decrease for the incremental capacity rider. Subsequently, in August 2012, Entergy Gulf States
Louisiana submitted a revised filing that reflected an earned return on common equity of 11.86%, which indicated a
$5.7 million cost of service rate decrease was necessary under the formula rate plan. The revised filing also indicated
that a reduction of $20.3 million should be reflected in the incremental capacity rider. The rate reductions were
implemented, subject to refund, effective for bills rendered in the first billing cycle of September 2012. Subsequently,
in December 2012, Entergy Gulf States Louisiana submitted a revised evaluation report that reflected expected retail
jurisdictional cost of $17 million for the first-year capacity charges for the purchase from Entergy Louisiana of onethird of Acadia Unit 2 capacity and energy. This rate change was implemented effective with the first billing cycle of
January 2013. The 2011 test year filings, as revised, were approved by the LPSC in February 2013. In April 2013,
Entergy Gulf States Louisiana submitted a revised evaluation report increasing the incremental capacity rider by
approximately $7.3 million to reflect the cost of an additional capacity contract.
In connection with its decision to extend the formula rate plan to the 2011 test year, the LPSC required that a
base rate case be filed by Entergy Gulf States Louisiana, and the required filing was made in February 2013. The filing
anticipated Entergy Gulf States Louisiana’s integration into MISO. In the filing Entergy Gulf States Louisiana requested,
among other relief:
•
•
•
•
authorization to increase the revenue it collects from customers by approximately $24 million;
an authorized return on common equity of 10.4%;
authorization to increase depreciation rates embedded in the proposed revenue requirement; and,
authorization to implement a three-year formula rate plan with a midpoint return on common equity of 10.4%,
plus or minus 75 basis points (the deadband), that would provide a means for the annual re-setting of rates
(commencing with calendar year 2013 as its first test year), that would include a mechanism to recover
incremental transmission revenue requirement on the basis of a forward-looking test year as compared to the
initial base year of 2014 with an annual true-up, that would retain the primary aspects of the prior formula rate
plan, including a 60% to customers/40% to Entergy Gulf States Louisiana sharing mechanism for earnings
outside the deadband, and a capacity rider mechanism that would permit recovery of incremental capacity
additions approved by the LPSC.
Following a hearing before an ALJ and the ALJ’s issuance of a Report of Proceedings, in December 2013 the
LPSC approved an unopposed settlement of the proceeding. Major terms of the settlement include approval of a threeyear formula rate plan (effective for test years 2014-2016) modeled after the formula rate plan in effect for Entergy
Gulf States Louisiana for 2011, including the following: (1) a midpoint return on equity of 9.95% plus or minus 80
basis points, with 60/40 sharing of earnings outside of the bandwidth; (2) recovery outside of the sharing mechanism
for the non-fuel MISO-related costs, additional capacity revenue requirement, extraordinary items, such as the Ninemile
6 project, and certain special recovery items; (3) three-year amortization of costs to achieve savings associated with
85
E-5 Page 33 of 182
Entergy Corporation and Subsidiaries
Notes to Financial Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41
the human capital management strategic imperative, with savings to be reflected as they are realized in subsequent
years; (4) eight-year amortization of costs incurred in connection with potential development of a new nuclear unit at
River Bend, without carrying costs, beginning December 2014, provided, however, that amortization of these costs
shall not result in a future rate increase; (5) no change in rates related to test year 2013, except with respect to recovery
of the non-fuel MISO-related costs and any changes to the additional capacity revenue requirement; and (6) no increase
in rates related to test year 2014, except for those items eligible for recovery outside of the earnings sharing mechanism.
Existing depreciation rates will not change. Implementation of rate changes for items recoverable outside of the
earnings sharing mechanism occurred in December 2014.
Pursuant to the rate case settlement approved by the LPSC in December 2013, Entergy Gulf States Louisiana
submitted a compliance filing in May 2014 reflecting the effects of the estimated MISO cost recovery mechanism
revenue requirement and adjustment of the additional capacity mechanism. In November 2014, Entergy Gulf States
Louisiana submitted an additional compliance filing updating the estimated MISO cost recovery mechanism for the
most recent actual data. Based on this updated filing, a net increase of $5.8 million in formula rate plan revenue to be
collected over nine months was implemented in December 2014. The compliance filings are subject to LPSC review
in accordance with the review process set forth in Entergy Gulf States Louisiana’s formula rate plan.
In July 2014, Entergy Gulf States Louisiana and Entergy Louisiana filed an unopposed stipulation with the
LPSC that estimated a first year revenue requirement associated with Ninemile 6 and provided a mechanism to update
the revenue requirement as the in-service date approached, which was subsequently approved by the LPSC. In late
December 2014, roughly contemporaneous with the unit's placement in service, a final updated estimated revenue
requirement of $26.8 million for Entergy Gulf States Louisiana was filed. The December 2014 estimate forms the
basis of rates implemented effective with the first billing cycle of January 2015.
(Entergy Louisiana)
In November 2011 the LPSC approved a one-year extension of Entergy Louisiana’s formula rate plan. In May
2012, Entergy Louisiana made its formula rate plan filing with the LPSC for the 2011 test year. The filing reflected a
9.63% earned return on common equity, which is within the earnings bandwidth and resulted in no cost of service rate
change under the formula rate plan. The filing also reflected an $18.1 million rate increase for the incremental capacity
rider. In August 2012, Entergy Louisiana submitted a revised filing that reflected an earned return on common equity
of 10.38%, which is still within the earnings bandwidth, resulting in no cost of service rate change. The revised filing
also indicated that an increase of $15.9 million should be reflected in the incremental capacity rider. The rate change
was implemented, subject to refund, effective for bills rendered the first billing cycle of September 2012. Subsequently,
in December 2012, Entergy Louisiana submitted a revised evaluation report that reflected two items: 1) a $17 million
reduction for the first-year capacity charges for the purchase by Entergy Gulf States Louisiana from Entergy Louisiana
of one-third of Acadia Unit 2 capacity and energy, and 2) an $88 million increase for the first-year retail revenue
requirement associated with the Waterford 3 replacement steam generator project, which was in-service in December
2012. These rate changes were implemented, subject to refund, effective with the first billing cycle of January 2013. In
April 2013, Entergy Louisiana and the LPSC staff filed a joint report resolving the 2011 test year formula rate plan
and recovery related to the Grand Gulf uprate. This report was approved by the LPSC in April 2013.
With completion of the Waterford 3 replacement steam generator project, the LPSC is conducting a prudence
review in connection with a filing made by Entergy Louisiana in April 2013 with regard to the following aspects of
the replacement project: 1) project management; 2) cost controls; 3) success in achieving stated objectives; 4) the costs
of the replacement project; and 5) the outage length and replacement power costs. In July 2014 the LPSC Staff filed
testimony recommending potential project and replacement power cost disallowances of up to $71 million, citing a
need for further explanation or documentation from Entergy Louisiana. An intervenor filed testimony recommending
disallowance of $141 million of incremental project costs, claiming the steam generator fabricator was imprudent.
Entergy Louisiana provided further documentation and explanation requested by the LPSC staff. An evidentiary hearing
was held in December 2014. At the hearing the parties maintained the positions reflected in pre-filed testimony. A
post-hearing briefing schedule has not been established. Entergy Louisiana believes that the replacement steam
86
E-5 Page 34 of 182
Entergy Corporation and Subsidiaries
Notes to Financial
Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc.
41
generator costs were prudently incurred and applicable legal principles support their recovery in rates. Nevertheless,
Entergy Louisiana recorded a write-off of $16 million of Waterford 3’s plant balance in December 2014 because of
the uncertainty associated with the resolution of the prudence review.
In connection with its decision to extend the formula rate plan to the 2011 test year, the LPSC required that a
base rate case be filed by Entergy Louisiana, and the required filing was made on February 15, 2013. The filing
anticipated Entergy Louisiana’s integration into MISO. In the filing Entergy Louisiana requested, among other relief:
•
•
•
•
authorization to increase the revenue it collects from customers by approximately $145 million (which does
not take into account a revenue offset of approximately $2 million resulting from a proposed increase for those
customers taking service under the Qualifying Facility Standby Service);
an authorized return on common equity of 10.4%;
authorization to increase depreciation rates embedded in the proposed revenue requirement; and,
authorization to implement a three-year formula rate plan with a midpoint return on common equity of 10.4%,
plus or minus 75 basis points (the deadband), that would provide a means for the annual re-setting of rates
(commencing with calendar year 2013 as its first test year), that would include a mechanism to recover
incremental transmission revenue requirement on the basis of a forward-looking test year as compared to the
initial base year of 2014 with an annual true-up, that would retain the primary aspects of the prior formula rate
plan, including a 60% to customers/40% to Entergy Louisiana sharing mechanism for earnings outside the
deadband, and a capacity rider mechanism that would permit recovery of incremental capacity additions
approved by the LPSC.
Following a hearing before an ALJ and the ALJ’s issuance of a Report of Proceedings, in December 2013 the
LPSC approved an unopposed settlement of the proceeding. The settlement provides for a $10 million rate increase
effective with the first billing cycle of December 2014. Major terms of the settlement include approval of a three-year
formula rate plan (effective for test years 2014-2016) modeled after the formula rate plan in effect for Entergy Louisiana
for 2011, including the following: (1) a midpoint return on equity of 9.95% plus or minus 80 basis points, with 60/40
sharing of earnings outside of the bandwidth; (2) recovery outside of the sharing mechanism for the non-fuel MISOrelated costs, additional capacity revenue requirement, extraordinary items, such as the Ninemile 6 project, and certain
special recovery items; (3) three-year amortization of costs to achieve savings associated with the human capital
management strategic imperative, with savings reflected as they are realized in subsequent years; (4) eight-year
amortization of costs incurred in connection with potential development of a new nuclear unit at River Bend, without
carrying costs, beginning December 2014, provided, however, that amortization of these costs shall not result in a
future rate increase; (5) recovery of non-fuel MISO-related costs and any changes to the additional capacity revenue
requirement related to test year 2013 effective with the first billing cycle of December 2014; and (6) a cumulative $30
million cap on cost of service increases over the three-year formula rate plan cycle, except for those items outside of
the sharing mechanism. Existing depreciation rates will not change.
Pursuant to the rate case settlement approved by the LPSC in December 2013, Entergy Louisiana submitted
a compliance filing in May 2014 reflecting the effects of the $10 million agreed-upon increase in formula rate plan
revenue, the estimated MISO cost recovery mechanism revenue requirement, and the adjustment of the additional
capacity mechanism. In November 2014, Entergy Louisiana submitted an additional compliance filing updating the
estimated MISO cost recovery mechanism for the most recent actual data, as well as providing for a refund and
prospective reduction in rates for the true-up of the estimated revenue requirement for the Waterford 3 replacement
steam generator project. Based on this updated filing, a net increase of $41.6 million in formula rate plan revenue to
be collected over nine months was implemented in December 2014. The compliance filings are subject to LPSC review
in accordance with the review process set forth in Entergy Louisiana’s formula rate plan. Additionally, the adjustments
of rates made related to the Waterford 3 replacement steam generator project included in the December 2014 compliance
filing are subject to final true-up following completion of the LPSC’s determination regarding the prudence of the
project.
87
E-5 Page 35 of 182
Entergy Corporation and Subsidiaries
Notes to Financial Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41
In July 2014, Entergy Gulf States Louisiana and Entergy Louisiana filed an unopposed stipulation with the
LPSC that estimated a first year revenue requirement associated with Ninemile 6 and provided a mechanism to update
the revenue requirement as the in-service date approached, which was subsequently approved by the LPSC. In late
December 2014, roughly contemporaneous with the unit's placement in service, a final updated estimated revenue
requirement of $51.1 million for Entergy Louisiana was filed. The December 2014 estimate forms the basis of rates
implemented effective with the first billing cycle of January 2015. Entergy Louisiana will submit project and cost
information to the LPSC in mid-2015 to enable the LPSC to review the prudence of Entergy Louisiana’s management
of the project.
Retail Rates - Gas (Entergy Gulf States Louisiana)
In January 2012, Entergy Gulf States Louisiana filed with the LPSC its gas rate stabilization plan for the test
year ended September 30, 2011. The filing showed an earned return on common equity of 10.48%, which is within
the earnings bandwidth of 10.5%, plus or minus fifty basis points. In April 2012 the LPSC Staff filed its findings,
suggesting adjustments that produced an 11.54% earned return on common equity for the test year and a $0.1 million
rate reduction. Entergy Gulf States Louisiana accepted the LPSC Staff’s recommendations, and the rate reduction was
effective with the first billing cycle of May 2012.
In January 2013, Entergy Gulf States Louisiana filed with the LPSC its gas rate stabilization plan for the test
year ended September 30, 2012. The filing showed an earned return on common equity of 11.18%, which results in
a $43 thousand rate reduction. In March 2013 the LPSC Staff issued its proposed findings and recommended two
adjustments. Entergy Gulf States Louisiana and the LPSC Staff reached agreement regarding the LPSC Staff’s proposed
adjustments. As reflected in an unopposed joint report of proceedings filed by Entergy Gulf States Louisiana and the
LPSC Staff in May 2013, Entergy Gulf States Louisiana accepted, with modification, the LPSC Staff’s proposed
adjustment to property insurance expense and agreed to: (1) a three-year extension of the gas rate stabilization plan
with a midpoint return on equity of 9.95%, with a first year midpoint reset; (2) dismissal of a docket initiated by the
LPSC to evaluate the allowed return on equity for Entergy Gulf States Louisiana’s gas rate stabilization plan; and (3)
presentation to the LPSC by November 2014 by Entergy Gulf States Louisiana and the LPSC Staff of their
recommendation for implementation of an infrastructure rider to recover expenditures associated with strategic plant
investment. The LPSC approved the agreement in May 2013.
In January 2014, Entergy Gulf States Louisiana filed with the LPSC its gas rate stabilization plan for the test
year ended September 30, 2013. The filing showed an earned return on common equity of 5.47%, which results in a
$1.5 million rate increase. In April 2014 the LPSC Staff issued a report indicating “that Entergy Gulf States Louisiana
has properly determined its earnings for the test year ended September 30, 2013.” The $1.5 million rate increase was
implemented effective with the first billing cycle of April 2014.
In accordance with the settlement of Entergy Gulf States Louisiana’s gas rate stabilization plan for the test
year ended September 30, 2012, in August 2014 Entergy Gulf States Louisiana submitted for consideration a proposal
for implementation of an infrastructure rider to recover expenditures associated with strategic plant investment and
relocation projects mandated by local governments. After review by the LPSC staff and inclusion of certain customer
safeguards required by the LPSC staff, in December 2014, Entergy Gulf States Louisiana and the LPSC staff submitted
a joint settlement for implementation of an accelerated gas pipe replacement program providing for the replacement
of approximately 100 miles of pipe over the next ten years, as well as relocation of certain existing pipe resulting from
local government-related infrastructure projects, and for a rider to recover the investment associated with these projects.
The rider allows for recovery of approximately $65 million over ten years. The rider recovery will be adjusted on a
quarterly basis to include actual investment incurred for the prior quarter and is subject to the following conditions,
among others: a ten-year term; application of any earnings in excess of 10.45% as an offset to the revenue requirement
of the infrastructure rider; adherence to a specified spending plan, within plus or minus 20 percent annually; annual
filings comparing actual versus planned rider spending with actual spending and explanation of variances exceeding
ten percent; and an annual true-up. The joint settlement was approved by the LPSC in January 2015. Implementation
of the infrastructure rider will commence with bills rendered on and after the first billing cycle of April 2015.
88
E-5 Page 36 of 182
Entergy Corporation and Subsidiaries
Notes to Financial
Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc.
41
In January 2015, Entergy Gulf States Louisiana filed with the LPSC its gas rate stabilization plan for the test
year ended September 30, 2014. The filing showed an earned return on common equity of 7.20%, which results in a
$706 thousand rate increase. The rate increase, if approved, will be implemented effective with the first billing cycle
of April 2015.
Filings with the MPSC (Entergy Mississippi)
Formula Rate Plan Filings
In September 2009, Entergy Mississippi filed with the MPSC proposed modifications to its formula rate plan
rider. In March 2010 the MPSC issued an order: (1) providing the opportunity for a reset of Entergy Mississippi’s
return on common equity to a point within the formula rate plan bandwidth and eliminating the 50/50 sharing that had
been in the plan, (2) modifying the performance measurement process, and (3) replacing the revenue change limit of
two percent of revenues, which was subject to a $14.5 million revenue adjustment cap, with a limit of four percent of
revenues, although any adjustment above two percent requires a hearing before the MPSC. The MPSC did not approve
Entergy Mississippi’s request to use a projected test year for its annual scheduled formula rate plan filing and, therefore,
Entergy Mississippi continued to use a historical test year for its annual evaluation reports under the plan.
In March 2012, Entergy Mississippi submitted its formula rate plan filing for the 2011 test year. The filing
shows an earned return on common equity of 10.92% for the test year, which is within the earnings bandwidth and
results in no change in rates. In February 2013 the MPSC approved a joint stipulation between Entergy Mississippi
and the Mississippi Public Utilities Staff that provided for no change in rates.
In March 2013, Entergy Mississippi submitted its formula rate plan filing for the 2012 test year. The filing
requested a $36.3 million revenue increase to reset Entergy Mississippi’s return on common equity to 10.55%, which
is a point within the formula rate plan bandwidth. In June 2013, Entergy Mississippi and the Mississippi Public Utilities
Staff entered into a joint stipulation, in which both parties agreed that the MPSC should approve a $22.3 million rate
increase for Entergy Mississippi which, with other adjustments reflected in the stipulation, would have the effect of
resetting Entergy Mississippi’s return on common equity to 10.59% when adjusted for performance under the formula
rate plan. In August 2013 the MPSC approved the joint stipulation between Entergy Mississippi and the Mississippi
Public Utilities Staff authorizing the rate increase effective with September 2013 bills. Additionally, the MPSC
authorized Entergy Mississippi to defer approximately $1.2 million in MISO-related implementation costs incurred in
2012 along with other MISO-related implementation costs incurred in 2013.
In June 2014, Entergy Mississippi filed its first general rate case before the MPSC in almost 12 years. The
rate filing laid out Entergy Mississippi’s plans for improving reliability, modernizing the grid, maintaining its workforce,
stabilizing rates, utilizing new technologies, and attracting new industry to its service territory. Entergy Mississippi
requested a net increase in revenue of $49 million for bills rendered during calendar year 2015, including $30 million
resulting from new depreciation rates to update the estimated service life of assets. In addition, the filing proposed,
among other things: 1) realigning cost recovery of the Attala and Hinds power plant acquisitions from the power
management rider to base rates; 2) including certain MISO-related revenues and expenses in the power management
rider; 3) power management rider changes that reflect the changes in costs and revenues that will accompany Entergy
Mississippi’s withdrawal from participation in the System Agreement; and 4) a formula rate plan forward test year to
allow for known changes in expenses and revenues for the rate effective period. Entergy Mississippi proposed
maintaining the current authorized return on common equity of 10.59%.
In October 2014, Entergy Mississippi and the Mississippi Public Utilities Staff entered into and filed joint
stipulations that addressed the majority of issues in the proceeding. The stipulations provided for:
•
an approximate $16 million net increase in revenues, which reflected an agreed upon 10.07% return on common
equity;
89
E-5 Page 37 of 182
Entergy Corporation and Subsidiaries
Notes to Financial Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41
•
•
•
•
revision of Entergy Mississippi’s formula rate plan by providing Entergy Mississippi with the ability to reflect
known and measurable changes to historical rate base and certain expense amounts; resolving uncertainty
around and obviating the need for an additional rate filing in connection with Entergy Mississippi’s withdrawal
from participation in the System Agreement; updating depreciation rates; and moving costs associated with
the Attala and Hinds generating plants from the power management rider to base rates;
recovery of non-fuel MISO-related costs through a separate rider for that purpose;
a deferral of $6 million in other operation and maintenance expenses associated with the Baxter Wilson outage
and a determination that the regulatory asset should accrue carrying costs, with amortization of the regulatory
asset over two years beginning in February 2015, and a provision that the capital costs will be reflected in rate
base. See Note 8 to the financial statements for further discussion of the Baxter Wilson outage; and
consolidation of the new nuclear generation development costs proceeding with the general rate case proceeding
for hearing purposes and a determination that Entergy Mississippi would not further pursue, except as noted
below, recovery of the costs that were approved for deferral by the MPSC in November 2011. The stipulations
state, however, that, if Entergy Mississippi decides to move forward with nuclear development in Mississippi,
it can at that time re-present for consideration by the MPSC only those costs directly associated with the existing
early site permit (ESP), to the extent that the costs are verifiable and prudent and the ESP is still valid and
relevant to any such option pursued. See "New Nuclear Generation Development Costs - Entergy
Mississippi" below for further discussion of the new nuclear generation development costs proceeding and
subsequent write-off in 2014 of the regulatory asset related to those costs.
In December 2014 the MPSC issued an order accepting the stipulations in their entirety and approving the revenue
adjustments and rate changes effective with February 2015 bills.
Filings with the City Council
(Entergy Louisiana)
In March 2013, Entergy Louisiana filed a rate case for the Algiers area, which is in New Orleans and is regulated
by the City Council. Entergy Louisiana is requesting a rate increase of $13 million over three years, including a 10.4%
return on common equity and a formula rate plan mechanism identical to its LPSC request. In January 2014, the City
Council Advisors filed direct testimony recommending a rate increase of $5.56 million over three years, including an
8.13% return on common equity. In June 2014 the City Council unanimously approved a settlement that includes the
following:
•
•
•
a $9.3 million base rate revenue increase to be phased in on a levelized basis over four years;
recovery of an additional $853 thousand annually through a MISO recovery rider; and
the adoption of a four-year formula rate plan requiring the filing of annual evaluation reports in May of each
year, commencing May 2015, with resulting rates being implemented in October of each year. The formula
rate plan includes a midpoint target authorized return on common equity of 9.95% with a +/- 40 basis point
bandwidth.
The rate increase was effective with bills rendered on and after the first billing cycle of July 2014. Additional compliance
filings were made with the Council in October 2014 for approval of the form of certain rate riders, including among
others, a Ninemile 6 non-fuel cost recovery interim rider, allowing for contemporaneous recovery of capacity costs
related to the commencement of commercial operation of the Ninemile 6 generating unit and a purchased power capacity
cost recovery rider. The Ninemile 6 cost recovery interim rider was implemented in December 2014 to collect $915
thousand from Entergy Louisiana customers in the Algiers area.
90
E-5 Page 38 of 182
Entergy Corporation and Subsidiaries
Notes to Financial
Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc.
41
(Entergy New Orleans)
Formula Rate Plan
In April 2009 the City Council approved a three-year formula rate plan for Entergy New Orleans, with terms
including an 11.1% benchmark electric return on common equity (ROE) with a +/-40 basis point bandwidth and a
10.75% benchmark gas ROE with a +/-50 basis point bandwidth. Earnings outside the bandwidth reset to the midpoint
benchmark ROE, with rates changing on a prospective basis depending on whether Entergy New Orleans was overor under-earning. The formula rate plan also included a recovery mechanism for City Council-approved capacity
additions, plus provisions for extraordinary cost changes and force majeure events.
In May 2012, Entergy New Orleans filed its electric and gas formula rate plan evaluation reports for the 2011
test year. Subsequent adjustments agreed upon with the City Council Advisors indicate a $4.9 million electric base
revenue increase and a $0.05 million gas base revenue increase as necessary under the formula rate plan. As part of
the original filing, Entergy New Orleans also requested to increase annual funding for its storm reserve by approximately
$5.7 million for five years. On September 26, 2012, Entergy New Orleans made a filing with the City Council that
implemented the $4.9 million electric formula rate plan rate increase and the $0.05 million gas formula rate plan rate
increase. The new rates were effective with the first billing cycle in October 2012. In August 2013 the City Council
unanimously approved a settlement of all issues in the formula rate plan proceeding. Pursuant to the terms of the
settlement, Entergy New Orleans implemented an approximately $1.625 million net decrease to the electric rates that
were in effect prior to the electric rate increase implemented in October 2012, with no change in gas rates. Entergy
New Orleans refunded to customers approximately $6 million over the four-month period from September 2013 through
December 2013 to make the electric rate decrease effective as of the first billing cycle of October 2012. Entergy New
Orleans had previously recorded provisions for the majority of the refund to customers, but recorded an additional
$1.1 million provision in second quarter 2013 as a result of the settlement. Entergy New Orleans’s formula rate plan
ended with the 2011 test year and has not been extended. Entergy New Orleans is recovering the costs of its power
purchase agreement with Entergy Louisiana for 20% of the capacity and energy of the Ninemile Unit 6 generating
station, which commenced operation in December 2014, through a special Ninemile Unit 6 rider.
A 2008 rate case settlement included $3.1 million per year in electric rates to fund the Energy Smart energy
efficiency programs. In September 2009 the City Council approved the energy efficiency programs filed by Entergy
New Orleans. The rate settlement provides an incentive for Entergy New Orleans to meet or exceed energy savings
targets set by the City Council and provides a mechanism for Entergy New Orleans to recover lost contribution to fixed
costs associated with the energy savings generated from the energy efficiency programs. In October 2013 the City
Council approved the extension of the current Energy Smart program through December 2014. The City Council
approved the use of $3.5 million of rough production cost equalization funds for program costs. In addition, Entergy
New Orleans will be allowed to recover its lost contribution to fixed costs and to earn an incentive for meeting program
goals. In January 2015 the City Council approved extending the Energy Smart program through March 2015 and using
$1.2 million of rough production cost equalization funds to cover program costs for the extended period. Additionally,
the City Council approved funding for the Energy Smart 2 programs from April 2015 through March 2017 using the
remainder of the approximately $12.8 million of 2014 rough production cost equalization funds, and with any remaining
costs being recovered through the fuel adjustment clause.
Filings with the PUCT and Texas Cities (Entergy Texas)
Retail Rates
2011 Rate Case
In November 2011, Entergy Texas filed a rate case requesting a $112 million base rate increase reflecting a
10.6% return on common equity based on an adjusted June 2011 test year. The rate case also proposed a purchased
power recovery rider. On January 12, 2012, the PUCT voted not to address the purchased power recovery rider in the
91
E-5 Page 39 of 182
Entergy Corporation and Subsidiaries
Notes to Financial Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41
current rate case, but the PUCT voted to set a baseline in the rate case proceeding that would be applicable if a purchased
power capacity rider is approved in a separate proceeding. In April 2012 the PUCT Staff filed direct testimony
recommending a base rate increase of $66 million and a 9.6% return on common equity. The PUCT Staff, however,
subsequently filed a statement of position in the proceeding indicating that it was still evaluating the position it would
ultimately take in the case regarding Entergy Texas’s recovery of purchased power capacity costs and Entergy Texas’s
proposal to defer its MISO transition expenses. In April 2012, Entergy Texas filed rebuttal testimony indicating a
revised request for a $105 million base rate increase. A hearing was held in late-April through early-May 2012.
In September 2012 the PUCT issued an order approving a $28 million rate increase, effective July 2012. The
order includes a finding that “a return on common equity (ROE) of 9.80 percent will allow [Entergy Texas] a reasonable
opportunity to earn a reasonable return on invested capital.” The order also provides for increases in depreciation rates
and the annual storm reserve accrual. The order also reduced Entergy Texas’s proposed purchased power capacity
costs, stating that they are not known and measurable; reduced Entergy Texas’s regulatory assets associated with
Hurricane Rita; excluded from rate recovery capitalized financially-based incentive compensation; included $1.6
million of MISO transition expense in base rates, and reduced Entergy’s Texas’s fuel reconciliation recovery by $4
million because it disagreed with the line-loss factor used in the calculation. After considering the progress of the
proceeding in light of the PUCT order, Entergy Texas recorded in the third quarter 2012 an approximate $24 million
charge to recognize that assets associated with Hurricane Rita, financially-based incentive compensation, and fuel
recovery are no longer probable of recovery. Entergy Texas continues to believe that it is entitled to recover these
prudently incurred costs, however, and it filed a motion for rehearing regarding these and several other issues in the
PUCT’s order on October 4, 2012. Several other parties have also filed motions for rehearing of the PUCT’s order. The
PUCT subsequently denied rehearing of substantive issues. Several parties, including Entergy Texas, have appealed
the PUCT’s order to the Travis County District Court. A hearing was held in July 2014. In October 2014 the Travis
County District Court issued an order upholding the PUCT’s decision except as to the line-loss factor issue referenced
above, which was found in favor of Entergy Texas. In November 2014, Entergy Texas appealed the Travis County
District Court decision and the PUCT appealed the decision on the line-loss factor issue. Entergy Texas expects to file
briefs during the first half of 2015.
2013 Rate Case
In September 2013, Entergy Texas filed a rate case requesting a $38.6 million base rate increase reflecting a
10.4% return on common equity based on an adjusted test year ending March 31, 2013. The rate case also proposed
(1) a rough production cost equalization adjustment rider recovering Entergy Texas’s payment to Entergy New Orleans
to achieve rough production cost equalization based on calendar year 2012 production costs and (2) a rate case expense
rider recovering the cost of the 2013 rate case and certain costs associated with previous rate cases. The rate case filing
also included a request to reconcile $0.9 billion of fuel and purchased power costs and fuel revenues covering the
period July 2011 through March 2013. The fuel reconciliation also reflects special circumstances fuel cost recovery
of approximately $22 million of purchased power capacity costs. In January 2014 the PUCT staff filed direct testimony
recommending a retail rate reduction of $0.3 million and a 9.2% return on common equity. In March 2014, Entergy
Texas filed an Agreed Motion for Interim Rates. The motion explained that the parties to this proceeding have agreed
that Entergy Texas should be allowed to implement new rates reflecting an $18.5 million base rate increase, effective
for usage on and after April 1, 2014, as well as recovery of charges for rough production cost equalization and rate
case expenses. In March 2014 the State Office of Administrative Hearings, the body assigned to hear the case, approved
the motion. In April 2014, Entergy Texas filed a unanimous stipulation in this case. Among other things, the stipulation
provides for an $18.5 million base rate increase, recovery over three years of the calendar year 2012 rough production
cost equalization charges and rate case expenses, and states a 9.8% return on common equity. In addition, the stipulation
finalizes the fuel and purchased power reconciliation covering the period July 2011 through March 2013, with the
parties stipulating an immaterial fuel disallowance. No special circumstances recovery of purchased power capacity
costs was allowed. In April 2014 the State Office of Administrative Hearings remanded the case back to the PUCT
for final processing. In May 2014 the PUCT approved the stipulation. No motions for rehearing were filed during the
statutory rehearing period.
92
E-5 Page 40 of 182
Entergy Corporation and Subsidiaries
Notes to Financial
Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc.
41
In September 2014, Entergy Texas filed for a distribution cost recovery factor rider based on a law that was
passed in 2011 allowing for the recovery of increases in capital costs associated with distribution plant. Entergy Texas
requested collection of approximately $7 million annually from retail customers. The parties reached a unanimous
settlement authorizing recovery of $3.6 million annually commencing with usage on and after January 1, 2015. A State
Office of Administrative Hearings ALJ issued an order in December 2014 authorizing this recovery on an interim basis
and remanded the case to the PUCT. In February 2015 the PUCT entered a final order, making the settlement final
and the interim rates permanent.
Entergy Louisiana and Entergy Gulf States Louisiana Business Combination
In June 2014, Entergy Louisiana and Entergy Gulf States Louisiana filed a business combination study report
with the LPSC. The report contained a preliminary analysis of the potential combination of Entergy Louisiana and
Entergy Gulf States Louisiana into a single public utility, including an overview of the combination that identified its
potential customer benefits. Although not part of the business combination, Entergy Louisiana provided notice to the
City Council in June 2014 that it would seek authorization to transfer to Entergy New Orleans the assets that currently
support the provision of service to Entergy Louisiana’s customers in Algiers. Entergy Louisiana subsequently filed
the referenced application with the City Council in October 2014. In the summer of 2014, Entergy Louisiana and
Entergy Gulf States Louisiana held technical conferences and face-to-face meetings with LPSC staff and other
stakeholders to discuss potential effects of the combination, solicit suggestions and concerns, and identify areas in
which additional information might be needed.
On September 30, 2014, Entergy Louisiana and Entergy Gulf States Louisiana filed an application with the
LPSC seeking authorization to undertake the transactions that would result in the combination of Entergy Louisiana
and Entergy Gulf States Louisiana into a single public utility.
The combination is subject to regulatory review and approval of the LPSC, the FERC, and the NRC. In June
2014, Entergy submitted an application to the NRC for approval of River Bend and Waterford 3 license transfers as
part of the steps to complete the business combination. The combination also could be subject to regulatory review
of the City Council if Entergy Louisiana continues to own the assets that currently support Entergy Louisiana’s customers
in Algiers at the time the combination is effectuated. In November 2014, Entergy Louisiana filed an application with
the City Council seeking authorization to undertake the combination. The application provides that if the City Council
approves the Algiers asset transfer before the business combination occurs, the City Council may not need to issue a
public interest finding regarding the combination. In December 2014, Entergy Louisiana and Entergy Gulf States
Louisiana filed applications with the FERC requesting authorization for the business combination and the Algiers asset
transfer. In January 2015, Entergy Services filed an application with the FERC for financing authority for the combined
company. If approvals are obtained from the LPSC, the FERC, the NRC, and, if required, the City Council, Entergy
Louisiana and Entergy Gulf States Louisiana expect the combination will be effected in the second half of 2015.
The procedural schedule in the LPSC business combination proceeding calls for LPSC Staff and intervenor
testimony to be filed in March 2015, with a hearing scheduled for June 2015. Entergy Louisiana and Entergy Gulf
States Louisiana have requested that the LPSC issue its decision regarding the business combination in August 2015.
In the City Council business combination proceeding, the City Council announced through a resolution that it would
not initiate an active review of the business combination filing, but instead would establish a business combination
docket for the limited purpose of receiving information filings relative to the business combination proceedings at the
LPSC.
It is currently contemplated that Entergy Louisiana and Entergy Gulf States Louisiana will undertake multiple
steps to effectuate the combination, which steps would include the following:
•
Each of Entergy Louisiana and Entergy Gulf States Louisiana will redeem or repurchase all of their
respective outstanding preferred membership interests (which interests have a $100 million liquidation
93
E-5 Page 41 of 182
Entergy Corporation and Subsidiaries
Notes to Financial Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41
•
•
•
•
•
value in the case of Entergy Louisiana and $10 million liquidation value in the case of Entergy Gulf States
Louisiana).
Entergy Gulf States Louisiana will convert from a Louisiana limited liability company to a Texas limited
liability company.
Under the Texas Business Organizations Code (TXBOC), Entergy Louisiana will allocate substantially
all of its assets to a new subsidiary (New Entergy Louisiana) and New Entergy Louisiana will assume all
of the liabilities of Entergy Louisiana, in a transaction regarded as a merger under the TXBOC. Entergy
Louisiana will remain in existence and hold the membership interests in New Entergy Louisiana.
Under the TXBOC, Entergy Gulf States Louisiana will allocate substantially all of its assets to a new
subsidiary (New Entergy Gulf States Louisiana) and New Entergy Gulf States Louisiana will assume all
of the liabilities of Entergy Gulf States Louisiana, in a transaction regarded as a merger under the TXBOC.
Entergy Gulf States Louisiana will remain in existence and hold the membership interests in New Entergy
Gulf States Louisiana.
Entergy Louisiana and Entergy Gulf States Louisiana will contribute the membership interests in New
Entergy Louisiana and New Entergy Gulf States Louisiana to an affiliate the common membership interests
of which will be owned by Entergy Louisiana, Entergy Gulf States Louisiana and Entergy Corporation.
New Entergy Gulf States Louisiana will merge into New Entergy Louisiana with New Entergy Louisiana
surviving the merger.
Upon the completion of the steps, New Entergy Louisiana will hold substantially all of the assets, and will
have assumed all of the liabilities, of Entergy Louisiana and Entergy Gulf States Louisiana. Entergy Louisiana and
Entergy Gulf States Louisiana may modify or supplement the steps to be taken to effect the combination.
Algiers Asset Transfer (Entergy Louisiana and Entergy New Orleans)
In October 2014, Entergy Louisiana and Entergy New Orleans filed an application with the City Council
seeking authorization to undertake a transaction that would result in the transfer from Entergy Louisiana to Entergy
New Orleans of certain assets that currently serve Entergy Louisiana’s customers in Algiers. The transaction is expected
to result in the transfer of net assets of approximately $60 million. The Algiers asset transfer is also subject to regulatory
review and approval of the FERC. As discussed previously, Entergy Louisiana also filed an application with the City
Council seeking authorization to undertake the Entergy Louisiana and Entergy Gulf States Louisiana business
combination. The application provides that if the City Council approves the Algiers asset transfer before the business
combination occurs, the City Council may not need to issue a public interest finding regarding the business combination.
If the necessary approvals are obtained from the City Council and the FERC, Entergy Louisiana expects to transfer
the Algiers assets to Entergy New Orleans in the second half of 2015. In November 2014 the City Council approved
a resolution establishing a procedural schedule that provides for a hearing on the joint application in late-May 2015,
with a decision to be rendered no later than June 2015.
System Agreement Cost Equalization Proceedings
The Utility operating companies historically have engaged in the coordinated planning, construction, and
operation of generating and bulk transmission facilities under the terms of the System Agreement, which is a rate
schedule that has been approved by the FERC. Certain of the Utility operating companies’ retail regulators and other
parties are pursuing litigation involving the System Agreement at the FERC. The proceedings include challenges to
the allocation of costs as defined by the System Agreement and allegations of imprudence by the Utility operating
companies in their execution of their obligations under the System Agreement.
In June 2005, the FERC issued a decision in System Agreement litigation that had been commenced by the
LPSC, and essentially affirmed its decision in a December 2005 order on rehearing. The FERC decision concluded,
among other things, that:
94
E-5 Page 42 of 182
Entergy Corporation and Subsidiaries
Notes to Financial
Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc.
41
•
•
•
•
The System Agreement no longer roughly equalizes total production costs among the Utility operating
companies.
In order to reach rough production cost equalization, the FERC imposed a bandwidth remedy by which each
company’s total annual production costs will have to be within +/- 11% of Entergy System average total annual
production costs.
In calculating the production costs for this purpose under the FERC’s order, output from the Vidalia
hydroelectric power plant will not reflect the actual Vidalia price for the year but is priced at that year’s average
price paid by Entergy Louisiana for the exchange of electric energy under Service Schedule MSS-3 of the
System Agreement, thereby reducing the amount of Vidalia costs reflected in the comparison of the Utility
operating companies’ total production costs.
The remedy ordered by FERC in 2005 required no refunds and became effective based on calendar year 2006
production costs and the first reallocation payments were made in 2007.
The FERC’s decision reallocates total production costs of the Utility operating companies whose relative total
production costs expressed as a percentage of Entergy System average production costs are outside an upper or lower
bandwidth. Under the current circumstances, this will be accomplished by payments from Utility operating companies
whose production costs are more than 11% below Entergy System average production costs to Utility operating
companies whose production costs are more than the Entergy System average production cost, with payments going
first to those Utility operating companies whose total production costs are farthest above the Entergy System average.
The financial consequences of the FERC’s decision are determined by the total production cost of each Utility
operating company, which are affected by the mix of solid fuel and gas-fired generation available to each company
and the costs of natural gas and purchased power. Entergy Louisiana, Entergy Gulf States Louisiana, Entergy Texas,
and Entergy Mississippi are more dependent upon gas-fired generation sources than Entergy Arkansas or Entergy New
Orleans. Of these, Entergy Arkansas is the least dependent upon gas-fired generation sources. Therefore, increases
in natural gas prices generally increased the amount by which Entergy Arkansas’s total production costs were below
the Entergy System average production costs.
The LPSC, APSC, MPSC, and the Arkansas Electric Energy Consumers appealed the FERC’s December 2005
decision to the United States Court of Appeals for the D.C. Circuit. Entergy and the City of New Orleans intervened
in the various appeals. The D.C. Circuit issued its decision in April 2008. The D.C. Circuit concluded that the FERC’s
orders had failed to adequately explain both its conclusion that it was prohibited from ordering refunds for the 20month period from September 13, 2001 - May 2, 2003 and its determination to implement the bandwidth remedy
commencing on January 1, 2006, rather than June 1, 2005. The D.C. Circuit remanded the case to the FERC for further
proceedings on these issues.
In October 2011, the FERC issued an order addressing the D.C. Circuit remand on these two issues. On the
first issue, the FERC concluded that it did have the authority to order refunds, but decided that it would exercise its
equitable discretion and not require refunds for the 20-month period from September 13, 2001 - May 2, 2003. Because
the ruling on refunds relied on findings in the interruptible load proceeding, which is discussed in a separate section
below, the FERC concluded that the refund ruling will be held in abeyance pending the outcome of the rehearing
requests in that proceeding. On the second issue, the FERC reversed its prior decision and ordered that the prospective
bandwidth remedy begin on June 1, 2005 (the date of its initial order in the proceeding) rather than January 1, 2006,
as it had previously ordered. Pursuant to the October 2011 order, Entergy was required to calculate the additional
bandwidth payments for the period June - December 2005 utilizing the bandwidth formula tariff prescribed by the
FERC that was filed in a December 2006 compliance filing and accepted by the FERC in an April 2007 order. As is
the case with bandwidth remedy payments, these payments and receipts will ultimately be paid by Utility operating
company customers to other Utility operating company customers.
95
E-5 Page 43 of 182
Entergy Corporation and Subsidiaries
Notes to Financial Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41
In December 2011, Entergy filed with the FERC its compliance filing that provides the payments and receipts
among the Utility operating companies pursuant to the FERC’s October 2011 order. The filing shows the following
payments/receipts among the Utility operating companies:
Entergy Arkansas
Entergy Gulf States Louisiana
Entergy Louisiana
Entergy Mississippi
Entergy New Orleans
Entergy Texas
Payments
(Receipts)
(In Millions)
$156
($75)
$—
($33)
($5)
($43)
Entergy Arkansas made its payment in January 2012. In February 2012, Entergy Arkansas filed for an interim
adjustment to its production cost allocation rider requesting that the $156 million payment be collected from customers
over the 22-month period from March 2012 through December 2013. In March 2012 the APSC issued an order stating
that the payment can be recovered from retail customers through the production cost allocation rider, subject to
refund. The LPSC and the APSC have requested rehearing of the FERC’s October 2011 order. In December 2013 the
LPSC filed a petition for a writ of mandamus at the United States Court of Appeals for the D.C. Circuit. In its petition,
the LPSC requested that the D.C. Circuit issue an order compelling the FERC to issue a final order on pending rehearing
requests. In its response to the LPSC petition, the FERC committed to rule on the pending rehearing request before
the end of February. In January 2014 the D.C. Circuit denied the LPSC’s petition. The APSC, the LPSC, the PUCT,
and other parties intervened in the December 2011 compliance filing proceeding, and the APSC and the LPSC also
filed protests.
In February 2014 the FERC issued a rehearing order addressing its October 2011 order. The FERC denied
the LPSC’s request for rehearing on the issues of whether the bandwidth remedy should be made effective earlier than
June 1, 2005, and whether refunds should be ordered for the 20-month refund effective period. The FERC granted the
LPSC’s rehearing request on the issue of interest on the bandwidth payments/receipts for the June - December 2005
period, requiring that interest be accrued from June 1, 2006 until the date those bandwidth payments/receipts are made.
Also in February 2014 the FERC issued an order rejecting the December 2011 compliance filing that calculated the
bandwidth payments/receipts for the June - December 2005 period. The FERC order required a new compliance filing
that calculates the bandwidth payments/receipts for the June - December 2005 period based on monthly data for the
seven individual months including interest pursuant to the February 2014 rehearing order. Entergy has sought rehearing
of the February 2014 orders with respect to the FERC’s determinations regarding interest. In April 2014 the LPSC
filed a petition for review of the FERC’s October 2011 and February 2014 orders with the U.S. Court of Appeals for
the D.C. Circuit. The appeal is currently being held in abeyance pending resolution of Entergy’s request for rehearing
with respect to the FERC’s determinations regarding interest.
In April and May 2014, Entergy filed with the FERC an updated compliance filing that provides the payments
and receipts among the Utility operating companies pursuant to the FERC’s February 2014 orders. The filing shows
the following net payments and receipts, including interest, among the Utility operating companies:
96
E-5 Page 44 of 182
Entergy Corporation and Subsidiaries
Notes to Financial
Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc.
41
Entergy Arkansas
Entergy Gulf States Louisiana
Entergy Louisiana
Entergy Mississippi
Entergy New Orleans
Entergy Texas
Payments
(Receipts)
(In Millions)
$68
($10)
$—
($11)
$2
($49)
These payments were made in May 2014. The LPSC, City Council, and APSC have filed protests.
Calendar Year 2014 Production Costs
Based on certain year-to-date information, Entergy preliminarily estimates that no payments and receipts are
required in 2015 to implement the FERC’s remedy based on calendar year 2014 production costs. The actual payments/
receipts for 2015, based on calendar year 2014 production costs, will not be calculated until the Utility operating
companies’ 2014 FERC Form 1s have been filed. Once the calculation is completed, it will be filed at the FERC. The
level of any payments and receipts is significantly affected by a number of factors, including, among others, weather,
the price of alternative fuels, the operating characteristics of the Entergy System generating fleet, and multiple factors
affecting the calculation of the non-fuel related revenue requirement components of the total production costs, such
as plant investment.
Rough Production Cost Equalization Rates
Each May since 2007 Entergy has filed with the FERC the rates to implement the FERC’s orders in the System
Agreement proceeding. These filings show the following payments/receipts among the Utility operating companies
are necessary to achieve rough production cost equalization as defined by the FERC’s orders:
Entergy Arkansas
Entergy Gulf States Louisiana
Entergy Louisiana
Entergy Mississippi
Entergy New Orleans
Entergy Texas
2007
2008
$252
($120)
($91)
($41)
$—
($30)
$252
($124)
($36)
($20)
($7)
($65)
Payments (Receipts)
2009
2010
2011
2012
(In Millions)
$390
$41
$77
$41
($107)
$—
($12)
$—
($140)
($22)
$—
($41)
($24)
($19)
($40)
$—
$—
$—
($25)
$—
($119)
$—
$—
$—
2013
$—
$—
$—
$—
($15)
$15
2014
$—
$—
$—
$—
($15)
$15
Entergy Arkansas is no longer a participant in the System Agreement and was not part of the calendar year
2013 or 2014 production costs calculations.
The APSC has approved a production cost allocation rider for recovery from customers of the retail portion
of the costs allocated to Entergy Arkansas. Entergy Texas proposed a rough production cost equalization adjustment
rider in its September 2013 rate filing, which is pending. Management believes that any changes in the allocation of
production costs resulting from the FERC’s decision and related retail proceedings should result in similar rate changes
for retail customers, subject to specific circumstances that have caused trapped costs. See “2007 Rate Filing Based
on Calendar Year 2006 Production Costs” below, however, for a discussion of a FERC decision that could result in
trapped costs at Entergy Arkansas related to a contract with AmerenUE.
97
E-5 Page 45 of 182
Entergy Corporation and Subsidiaries
Notes to Financial Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41
Entergy Arkansas and, for December 2012 and 2013, Entergy Texas, record accounts payable and Entergy
Gulf States Louisiana, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas record
accounts receivable to reflect the rough production cost equalization payments and receipts required to implement the
FERC’s remedy. Entergy Arkansas and, for December 2012 and 2013, Entergy Texas, record a corresponding
regulatory asset for the right to collect the payments from customers, and Entergy Gulf States Louisiana, Entergy
Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas record corresponding regulatory liabilities
for their obligations to pass the receipts on to customers. The regulatory asset and liabilities are shown as “System
Agreement cost equalization” on the respective balance sheets.
2007 Rate Filing Based on Calendar Year 2006 Production Costs
Several parties intervened in the 2007 rate proceeding at the FERC, including the APSC, the MPSC, the Council,
and the LPSC, which also filed protests. The PUCT also intervened. Intervenor testimony was filed in which the
intervenors and also the FERC Staff advocated a number of positions on issues that affect the level of production costs
the individual Utility operating companies are permitted to reflect in the bandwidth calculation, including the level of
depreciation and decommissioning expense for nuclear facilities. The effect of the various positions would be to
reallocate costs among the Utility operating companies. The Utility operating companies filed rebuttal testimony
explaining why the bandwidth payments are properly recoverable under the AmerenUE contract, and explaining why
the positions of FERC Staff and intervenors on the other issues should be rejected. A hearing in this proceeding
concluded in July 2008, and the ALJ issued an initial decision in September 2008. The ALJ’s initial decision concluded,
among other things, that: (1) the decisions to not exercise Entergy Arkansas’s option to purchase the Independence
plant in 1996 and 1997 were prudent; (2) Entergy Arkansas properly flowed a portion of the bandwidth payments
through to AmerenUE in accordance with the wholesale power contract; and (3) the level of nuclear depreciation and
decommissioning expense reflected in the bandwidth calculation should be calculated based on NRC-authorized license
life, rather than the nuclear depreciation and decommissioning expense authorized by the retail regulators for purposes
of retail ratemaking. Following briefing by the parties, the matter was submitted to the FERC for decision. On January
11, 2010, the FERC issued its decision both affirming and overturning certain of the ALJ’s rulings, including overturning
the decision on nuclear depreciation and decommissioning expense. The FERC’s conclusion related to the AmerenUE
contract does not permit Entergy Arkansas to recover a portion of its bandwidth payment from AmerenUE. The Utility
operating companies requested rehearing of that portion of the decision and requested clarification on certain other
portions of the decision.
AmerenUE argued that its wholesale power contract with Entergy Arkansas, pursuant to which Entergy
Arkansas sells power to AmerenUE, does not permit Entergy Arkansas to flow through to AmerenUE any portion of
Entergy Arkansas’s bandwidth payment. The AmerenUE contract expired in August 2009. In April 2008, AmerenUE
filed a complaint with the FERC seeking refunds, plus interest, in the event the FERC ultimately determines that
bandwidth payments are not properly recovered under the AmerenUE contract. In response to the FERC’s decision
discussed in the previous paragraph, Entergy Arkansas recorded a regulatory provision in the fourth quarter 2009 for
a potential refund to AmerenUE.
In May 2012, the FERC issued an order on rehearing in the proceeding. The order may result in the reallocation
of costs among the Utility operating companies, although there are still FERC decisions pending in other System
Agreement proceedings that could affect the rough production cost equalization payments and receipts. The FERC
directed Entergy, within 45 days of the issuance of a pending FERC order on rehearing regarding the functionalization
of costs in the 2007 rate filing, to file a comprehensive bandwidth recalculation report showing updated payments and
receipts in the 2007 rate filing proceeding. The May 2012 FERC order also denied Entergy’s request for rehearing
regarding the AmerenUE contract and ordered Entergy Arkansas to refund to AmerenUE the rough production cost
equalization payments collected from AmerenUE. Under the terms of the FERC’s order a refund of $30.6 million,
including interest, was made in June 2012. Entergy and the LPSC appealed certain aspects of the FERC’s decisions
to the U.S. Court of Appeals for the D.C. Circuit. On December 7, 2012, the D.C. Circuit dismissed Entergy’s petition
for review as premature because Entergy filed a rehearing request of the May 2012 FERC order and that rehearing
request is still pending. The court also ordered that the LPSC’s appeal be held in abeyance and that the parties file
98
E-5 Page 46 of 182
Entergy Corporation and Subsidiaries
Notes to Financial
Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc.
41
motions to govern further proceedings within 30 days of the FERC’s completion of the ongoing “Entergy bandwidth
proceedings.” On October 16, 2013, the FERC issued two orders related to this proceeding. The first order provided
clarification with regard to the derivation of the ratio that should be used to functionalize net operating loss carryforwards
for purposes of the annual bandwidth filings. The first order required a compliance filing that Entergy made in November
2013. The second order denied Entergy’s request for rehearing of the FERC’s prior determination that interest should
be included on recalculated payment and receipt amounts required in this particular proceeding due to the length of
time that had passed. Entergy subsequently appealed certain aspects of the FERC’s decisions to the U.S. Court of
Appeals for the D.C. Circuit. On January 23, 2014, the D.C. Circuit returned the LPSC’s appeal to the active docket
and consolidated it with Entergy’s petition for appellate review. The appeals are pending. In July 2014 the FERC
issued an order accepting Entergy Services’ November 2013 compliance filing. The FERC directed Entergy Services
to make a comprehensive bandwidth recalculation report by September 15, 2014 showing all the updated payment/
receipt amounts based on the 2006 calendar year data in compliance with all bandwidth formula and bandwidth
calculation adjustments that the FERC has accepted or ordered for those years. The FERC also directed the Entergy
Operating Companies to make any true-up bandwidth payments associated with the 2006 bandwidth recalculation
report with interest following the filing of the comprehensive recalculation report. See discussion below regarding
the comprehensive bandwidth recalculation and filings made with the FERC in connection with this proceeding.
2008 Rate Filing Based on Calendar Year 2007 Production Costs
Several parties intervened in the 2008 rate proceeding at the FERC, including the APSC, the LPSC, and
AmerenUE, which also filed protests. Several other parties, including the MPSC and the City Council, intervened in
the proceeding without filing a protest. In direct testimony filed in January 2009, certain intervenors and the FERC
staff advocated a number of positions on issues that affect the level of production costs the individual Utility operating
companies are permitted to reflect in the bandwidth calculation, including the level of depreciation and decommissioning
expense for the nuclear and fossil-fueled generating facilities. The effect of these various positions would be to
reallocate costs among the Utility operating companies. In addition, three issues were raised alleging imprudence by
the Utility operating companies, including whether the Utility operating companies had properly reflected generating
units’ minimum operating levels for purposes of making unit commitment and dispatch decisions, whether Entergy
Arkansas’s sales to third parties from its retained share of the Grand Gulf nuclear facility were reasonable, prudent,
and non-discriminatory, and whether Entergy Louisiana’s long-term Evangeline gas purchase contract was prudent
and reasonable.
The parties reached a partial settlement agreement of certain of the issues initially raised in this proceeding. The
partial settlement agreement was conditioned on the FERC accepting the agreement without modification or condition,
which the FERC did in August 2009. A hearing on the remaining issues in the proceeding was completed in June 2009,
and in September 2009 the ALJ issued an initial decision. The initial decision affirms Entergy’s position in the filing,
except for two issues that may result in a reallocation of costs among the Utility operating companies. In October 2011
the FERC issued an order on the ALJ’s initial decision. The FERC’s order resulted in a minor reallocation of payments/
receipts among the Utility operating companies on one issue in the 2008 rate filing. Entergy made a compliance filing
in December 2011 showing the updated payment/receipt amounts. The LPSC filed a protest in response to the
compliance filing. In January 2013 the FERC issued an order accepting Entergy’s compliance filing. In the January
2013 order the FERC required Entergy to include interest on the recalculated bandwidth payment and receipt amounts
for the period from June 1, 2008 until the date of the Entergy intra-system bill that will reflect the bandwidth recalculation
amounts for calendar year 2007. In February 2013, Entergy filed a request for rehearing of the FERC’s ruling requiring
interest. In March 2013 the LPSC filed a petition for review with the U.S. Court of Appeals for the Fifth Circuit seeking
appellate review of the FERC’s earlier orders addressing the ALJ’s initial decision. In July 2014 the FERC issued an
order denying Entergy’s rehearing request and decided that it is appropriate to allow interest to be paid on the bandwidth
recalculation amounts. The FERC also directed Entergy to file a comprehensive bandwidth recalculation report by
September 15, 2014 showing all the updated payment/receipt amounts based on the 2007 calendar year data in
compliance with all bandwidth formula and bandwidth calculation adjustments that the FERC has accepted or ordered
for that year. The FERC also directed the Entergy Operating Companies to make any true-up bandwidth payments
associated with the 2007 bandwidth recalculation report with interest following the filing of the comprehensive
99
E-5 Page 47 of 182
Entergy Corporation and Subsidiaries
Notes to Financial Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41
recalculation report. In August 2014 the Fifth Circuit issued its opinion dismissing in part and denying in part the
LPSC petition for review of the FERC’s order. In December 2014 the LPSC petitioned the U.S. Supreme Court for a
writ of certiorari of the Fifth Circuit’s decision. In September 2014, Entergy filed a petition for review with the U.S.
Court of Appeals for the D.C. Circuit seeking appellate review of the FERC’s interest determination. See discussion
below regarding the comprehensive bandwidth recalculation and filings made with the FERC in connection with this
proceeding.
2009 Rate Filing Based on Calendar Year 2008 Production Costs
Several parties intervened in the 2009 rate proceeding at the FERC, including the LPSC and Ameren, which
also filed protests. In July 2009 the FERC accepted Entergy’s proposed rates for filing, effective June 1, 2009, subject
to refund, and set the proceeding for hearing and settlement procedures. Settlement procedures were terminated and
a hearing before the ALJ was held in April 2010. In August 2010 the ALJ issued an initial decision. The initial decision
substantially affirms Entergy’s position in the filing, except for one issue that may result in some reallocation of costs
among the Utility operating companies. The LPSC, the FERC trial staff, and Entergy submitted briefs on exceptions
in the proceeding. In May 2012 the FERC issued an order affirming the ALJ’s initial decision, or finding certain issues
in that decision moot. Rehearing and clarification of FERC’s order have been requested. In January 2013 the LPSC
filed a protest of Entergy’s July 2012 compliance filing submitted in response to the FERC’s May 2012 order. In
October 2013 the FERC issued orders denying the LPSC’s rehearing request with respect to the FERC’s May 2012
order and addressing Entergy’s compliance filing implementing the FERC’s directives in the May 2012 order. The
compliance filing order referred to guidance provided in a separate order issued on that same day in the 2007 rate
proceeding with respect to the ratio used to functionalize net operating loss carryforwards for bandwidth purposes and
directed Entergy to make an additional compliance filing in the 2009 rate proceeding consistent with the guidance
provided in that order. In November 2013 the LPSC sought rehearing of the FERC’s October 2013 order and Entergy
submitted its compliance filing implementing the FERC’s directives in the October 2013 order. In August 2014, the
FERC issued an order accepting the November 2013 compliance filing that was made in response to the FERC’s
October 2013 order. The LPSC appealed to the U.S. Court of Appeals for the Fifth Circuit the FERC’s May 2012 and
October 2013 orders. In November 2014 the Fifth Circuit issued its opinion denying the LPSC petition for review of
the FERC’s order. In December 2014 the LPSC petitioned the U.S. Supreme Court for a writ of certiorari of the Fifth
Circuit’s decision. See discussion below regarding the comprehensive bandwidth recalculation and filings made with
the FERC in connection with this proceeding.
Comprehensive Bandwidth Recalculation for 2007, 2008, and 2009 Rate Filing Proceedings
In July 2014 the FERC issued four orders in connection with various Service Schedule MSS-3 rough production
cost equalization formula compliance filings and rehearing requests. Specifically, the FERC accepted Entergy Services’
revised methodologies for calculating certain cost components of the formula and affirmed its prior ruling requiring
interest on the true-up amounts. The FERC directed that a comprehensive recalculation of the formula be performed
for the filing years 2007, 2008, and 2009 based on calendar years 2006, 2007, and 2008 production costs. In September
2014, Entergy filed with the FERC its compliance filing that provides the payments and receipts, including interest,
among the Utility operating companies pursuant to the FERC’s orders for the 2007, 2008, and 2009 rate filing
proceedings. The filing shows the following additional payments/receipts among the Utility operating companies:
100
E-5 Page 48 of 182
Entergy Corporation and Subsidiaries
Notes to Financial
Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc.
41
Entergy Arkansas
Entergy Gulf States Louisiana
Entergy Louisiana
Entergy Mississippi
Entergy New Orleans
Entergy Texas
Payments
(Receipts)
(In Millions)
$38
($22)
($16)
$16
($1)
($15)
Entergy Arkansas and Entergy Mississippi made the payments in September and October 2014. The updated
compliance filings in the 2008 and 2009 rate filing proceedings have not been protested, and one protest was filed at
the FERC related to the 2007 rate filing proceeding. The filings are pending at the FERC.
2010 Rate Filing Based on Calendar Year 2009 Production Costs
In May 2010, Entergy filed with the FERC the 2010 rates in accordance with the FERC’s orders in the System
Agreement proceeding, and supplemented the filing in September 2010. Several parties intervened in the proceeding
at the FERC, including the LPSC and the City Council, which also filed protests. In July 2010 the FERC accepted
Entergy’s proposed rates for filing, effective June 1, 2010, subject to refund, and set the proceeding for hearing and
settlement procedures. Settlement procedures have been terminated, and the ALJ scheduled hearings to begin in March
2011. Subsequently, in January 2011 the ALJ issued an order directing the parties and FERC Staff to show cause why
this proceeding should not be stayed pending the issuance of FERC decisions in the prior production cost proceedings
currently before the FERC on review. In March 2011 the ALJ issued an order placing this proceeding in abeyance. In
October 2013 the FERC issued an order granting clarification and denying rehearing with respect to its October 2011
rehearing order in this proceeding. The FERC clarified that in a bandwidth proceeding parties can challenge erroneous
inputs, implementation errors, or prudence of cost inputs, but challenges to the bandwidth formula itself must be raised
in a Federal Power Act section 206 complaint or section 205 filing. Subsequently in October 2013 the presiding ALJ
lifted the stay order holding in abeyance the hearing previously ordered by the FERC and directing that the remaining
issues proceed to a hearing on the merits. The hearing was held in March 2014 and the presiding ALJ issued an initial
decision in September 2014. Briefs on exception were filed in October 2014, and the case is pending before the FERC.
2011 Rate Filing Based on Calendar Year 2010 Production Costs
In May 2011, Entergy filed with the FERC the 2011 rates in accordance with the FERC’s orders in the System
Agreement proceeding. Several parties intervened in the proceeding at the FERC, including the LPSC, which also
filed a protest. In July 2011 the FERC accepted Entergy’s proposed rates for filing, effective June 1, 2011, subject to
refund, set the proceeding for hearing procedures, and then held those procedures in abeyance pending FERC decisions
in the prior production cost proceedings currently before the FERC on review. In January 2014 the LPSC filed a
petition for a writ of mandamus at the United States Court of Appeals for the Fifth Circuit. In its petition, the LPSC
requested that the Fifth Circuit issue an order compelling the FERC to issue a final order in several proceedings related
to the System Agreement, including the 2011 rate filing based on calendar year 2010 production costs and the 2012
and 2013 rate filings discussed below. In March 2014 the Fifth Circuit rejected the LPSC’s petition for a writ of
mandamus. In December 2014 the FERC rescinded its earlier abeyance order and consolidated the 2011 Rate Filing
with the 2012, 2013, and 2014 Rate Filings for settlement and hearing procedures. A procedural schedule was adopted
in February 2015, and a hearing on the merits is scheduled for November 2015.
2012 Rate Filing Based on Calendar Year 2011 Production Costs
In May 2012, Entergy filed with the FERC the 2012 rates in accordance with the FERC’s orders in the System
Agreement proceeding. Several parties intervened in the proceeding at the FERC, including the LPSC, which also
101
E-5 Page 49 of 182
Entergy Corporation and Subsidiaries
Notes to Financial Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41
filed a protest. In August 2012 the FERC accepted Entergy’s proposed rates for filing, effective June 2012, subject to
refund, set the proceeding for hearing procedures, and then held those procedures in abeyance pending FERC decisions
in the prior production cost proceedings currently before the FERC on review. In December 2014 the FERC rescinded
its earlier abeyance order and consolidated the 2012 Rate Filing with the 2011, 2013, and 2014 Rate Filings for settlement
and hearing procedures. A procedural schedule was adopted in February 2015, and a hearing on the merits is scheduled
for November 2015.
2013 Rate Filing Based on Calendar Year 2012 Production Costs
In May 2013, Entergy filed with the FERC the 2013 rates in accordance with the FERC’s orders in the System
Agreement proceeding. Several parties intervened in the proceeding at the FERC, including the LPSC, which also
filed a protest. The City Council intervened and filed comments related to including the outcome of a related FERC
proceeding in the 2013 cost equalization calculation. In August 2013 the FERC issued an order accepting the 2013
rates, effective June 1, 2013, subject to refund, set the proceeding for hearing procedures, and then held those procedures
in abeyance pending FERC decisions in the prior production cost proceedings currently before the FERC on review.
In December 2014 the FERC rescinded its earlier abeyance order and consolidated the 2013 Rate Filing with the 2011,
2012, and 2014 Rate Filings for settlement and hearing procedures. A procedural schedule was adopted in February
2015, and a hearing on the merits is scheduled for November 2015.
2014 Rate Filing Based on Calendar Year 2013 Production Costs
In May 2014, Entergy filed with the FERC the 2014 rates in accordance with the FERC’s orders in the System
Agreement proceeding. Several parties intervened in the proceeding at the FERC, including the LPSC, which also
filed a protest. The City Council intervened and filed comments. In December 2014 the FERC issued an order accepting
the 2014 rates, effective June 1, 2014, subject to refund, set the proceeding for hearing procedures, and consolidated
the 2014 Rate Filing with the 2011, 2012, and 2013 Rate Filings for settlement and hearing procedures. A procedural
schedule was adopted in February 2015, and a hearing on the merits is scheduled for November 2015.
Interruptible Load Proceeding
In April 2007, the U.S. Court of Appeals for the D.C. Circuit issued its opinion in the LPSC’s appeal of the
FERC’s March 2004 and April 2005 orders related to the treatment under the System Agreement of the Utility operating
companies’ interruptible loads. In its opinion the D.C. Circuit concluded that the FERC (1) acted arbitrarily and
capriciously by allowing the Utility operating companies to phase-in the effects of the elimination of the interruptible
load over a 12-month period of time; (2) failed to adequately explain why refunds could not be ordered under Section
206(c) of the Federal Power Act; and (3) exercised appropriately its discretion to defer addressing the cost of sulfur
dioxide allowances until a later time. The D.C. Circuit remanded the matter to the FERC for a more considered
determination on the issue of refunds. The FERC issued its order on remand in September 2007, in which it directed
Entergy to make a compliance filing removing all interruptible load from the computation of peak load responsibility
commencing April 1, 2004 and to issue any necessary refunds to reflect this change. In addition, the order directed
the Utility operating companies to make refunds for the period May 1995 through July 1996. In November 2007 the
Utility operating companies filed a refund report describing the refunds to be issued pursuant to the FERC’s orders. The
LPSC filed a protest to the refund report in December 2007, and the Utility operating companies filed an answer to
the protest in January 2008. The refunds were made in October 2008 by the Utility operating companies that owed
refunds to the Utility operating companies that were due a refund under the decision. The APSC and the Utility
operating companies appealed the FERC decisions to the D.C. Circuit. The refunds were made in the fourth quarter
2009.
Following the filing of petitioners’ initial briefs, the FERC filed a motion requesting the D.C. Circuit hold the
appeal of the FERC’s decisions ordering refunds in the interruptible load proceeding in abeyance and remand the record
to the FERC. The D.C. Circuit granted the FERC’s unopposed motion in June 2009. In December 2009 the FERC
established a paper hearing to determine whether the FERC had the authority and, if so, whether it would be appropriate
102
E-5 Page 50 of 182
Entergy Corporation and Subsidiaries
Notes to Financial
Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc.
41
to order refunds resulting from changes in the treatment of interruptible load in the allocation of capacity costs by the
Utility operating companies. In August 2010 the FERC issued an order stating that it has the authority and refunds
are appropriate. The APSC, MPSC, and Entergy requested rehearing of the FERC’s decision. In June 2011 the FERC
issued an order granting rehearing in part and denying rehearing in part, in which the FERC determined to invoke its
discretion to deny refunds. The FERC held that in this case where “the Entergy system as a whole collected the proper
level of revenue, but, as was later established, incorrectly allocated peak load responsibility among the various Entergy
operating companies….the Commission will apply here our usual practice in such cases, invoking our equitable
discretion to not order refunds, notwithstanding our authority to do so.” The LPSC has requested rehearing of the
FERC’s June 2011 decision. In July 2011 the refunds made in the fourth quarter 2009 described above were reversed.
In October 2011 the FERC issued an “Order Establishing Paper Hearing” inviting parties that oppose refunds to file
briefs within 30 days addressing the LPSC’s argument that FERC precedent supports refunds under the circumstances
present in this proceeding. Parties that favor refunds were then invited to file reply briefs within 21 days of the date
that the initial briefs are due. Briefs were submitted and the matter is pending.
In September 2010 the FERC had issued an order setting the refund report filed in the proceeding in November
2007 for hearing and settlement judge procedures. In May 2011, Entergy filed a settlement agreement that resolved
all issues relating to the refund report set for hearing. In June 2011 the settlement judge certified the settlement as
uncontested and the settlement agreement is currently pending before the FERC. In July 2011, Entergy filed an
amended/corrected refund report and a motion to defer action on the settlement agreement until after the FERC rules
on the LPSC’s rehearing request regarding the June 2011 decision denying refunds.
Prior to the FERC’s June 2011 order on rehearing, Entergy Arkansas filed an application in November 2010
with the APSC for recovery of the refund that it paid. The APSC denied Entergy Arkansas’s application, and also
denied Entergy Arkansas’s petition for rehearing. If the FERC were to order Entergy Arkansas to pay refunds on
rehearing in the interruptible load proceeding the APSC’s decision would trap FERC-approved costs at Entergy Arkansas
with no regulatory-approved mechanism to recover them. In August 2011, Entergy Arkansas filed a complaint in the
United States District Court for the Eastern District of Arkansas asking for a declaratory judgment that the rejection
of Entergy Arkansas’s application by the APSC is preempted by the Federal Power Act. The APSC filed a motion to
dismiss the complaint. In April 2012 the United States district court dismissed Entergy Arkansas’s complaint without
prejudice stating that Entergy Arkansas’s claim is not ripe for adjudication and that Entergy Arkansas did not have
standing to bring suit at this time.
In March 2013 the FERC issued an order denying the LPSC’s request for rehearing of the FERC’s June 2011
order wherein the FERC concluded it would exercise its discretion and not order refunds in the interruptible load
proceeding. Based on its review of the LPSC’s request for rehearing and the briefs filed as part of the paper hearing
established in October 2011, the FERC affirmed its earlier ruling and declined to order refunds under the circumstances
of the case. In May 2013 the LPSC filed a petition for review with the U.S. Court of Appeals for the D.C. Circuit
seeking review of FERC prior orders in the Interruptible Load Proceeding that concluded that the FERC would exercise
its discretion and not order refunds in the proceeding. Oral argument was held on the appeal in the D.C. Circuit in
September 2014. In December 2014 the D.C. Circuit issued an order on the LPSC’s appeal and remanded the case
back to the FERC. The D.C. Circuit rejected the LPSC’s argument that there is a presumption in favor of refunds, but
it held that the FERC had not adequately explained its decision to deny refunds and directed the FERC “to consider
the relevant factors and weigh them against one another.”
Entergy Arkansas Opportunity Sales Proceeding
In June 2009, the LPSC filed a complaint requesting that the FERC determine that certain of Entergy Arkansas’s
sales of electric energy to third parties: (a) violated the provisions of the System Agreement that allocate the energy
generated by Entergy System resources, (b) imprudently denied the Entergy System and its ultimate consumers the
benefits of low-cost Entergy System generating capacity, and (c) violated the provision of the System Agreement that
prohibits sales to third parties by individual companies absent an offer of a right-of-first-refusal to other Utility operating
companies. The LPSC’s complaint challenges sales made beginning in 2002 and requests refunds. In July 2009 the
103
E-5 Page 51 of 182
Entergy Corporation and Subsidiaries
Notes to Financial Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41
Utility operating companies filed a response to the complaint requesting that the FERC dismiss the complaint on the
merits without hearing because the LPSC has failed to meet its burden of showing any violation of the System Agreement
and failed to produce any evidence of imprudent action by the Entergy System. In their response, the Utility operating
companies explained that the System Agreement clearly contemplates that the Utility operating companies may make
sales to third parties for their own account, subject to the requirement that those sales be included in the load (or load
shape) for the applicable Utility operating company. The response further explained that the FERC already had
determined that Entergy Arkansas’s short-term wholesale sales did not trigger the “right-of-first-refusal” provision of
the System Agreement. While the D.C. Circuit recently determined that the “right-of-first-refusal” issue was not
properly before the FERC at the time of its earlier decision on the issue, the LPSC raised no additional claims or facts
that would warrant the FERC reaching a different conclusion.
The LPSC filed direct testimony in the proceeding alleging, among other things, (1) that Entergy violated the
System Agreement by permitting Entergy Arkansas to make non-requirements sales to non-affiliated third parties rather
than making such energy available to the other Utility operating companies’ customers; and (2) that over the period
2000 - 2009, these non-requirements sales caused harm to the Utility operating companies’ customers and these
customers should be compensated for this harm by Entergy. In subsequent testimony, the LPSC modified its original
damages claim in favor of quantifying damages by re-running intra-system bills. The Utility operating companies
believe the LPSC’s allegations are without merit. A hearing in the matter was held in August 2010.
In December 2010, the ALJ issued an initial decision. The ALJ found that the System Agreement allowed for
Entergy Arkansas to make the sales to third parties but concluded that the sales should be accounted for in the same
manner as joint account sales. The ALJ concluded that “shareholders” should make refunds of the damages to the
Utility operating companies, along with interest. Entergy disagreed with several aspects of the ALJ’s initial decision
and in January 2011 filed with the FERC exceptions to the decision.
The FERC issued a decision in June 2012 and held that, while the System Agreement is ambiguous, it does
provide authority for individual Utility operating companies to make opportunity sales for their own account and
Entergy Arkansas made and priced these sales in good faith. The FERC found, however, that the System Agreement
does not provide authority for an individual Utility operating company to allocate the energy associated with such
opportunity sales as part of its load, but provides a different allocation authority. The FERC further found that the
after-the-fact accounting methodology used to allocate the energy used to supply the sales was inconsistent with the
System Agreement. Quantifying the effect of the FERC’s decision will require re-running intra-system bills for a tenyear period, and the FERC in its decision established further hearing procedures to determine the calculation of the
effects. In July 2012, Entergy and the LPSC filed requests for rehearing of the FERC’s June 2012 decision, which are
pending with the FERC.
As required by the procedural schedule established in the calculation proceeding, Entergy filed its direct
testimony that included a proposed illustrative re-run, consistent with the directives in FERC’s order, of intra-system
bills for 2003, 2004, and 2006, the three years with the highest volume of opportunity sales. Entergy’s proposed
illustrative re-run of intra-system bills shows that the potential cost for Entergy Arkansas would be up to $12 million
for the years 2003, 2004, and 2006, excluding interest, and the potential benefit would be significantly less than that
for each of the other Utility operating companies. Entergy’s proposed illustrative re-run of the intra-system bills also
shows an offsetting potential benefit to Entergy Arkansas for the years 2003, 2004, and 2006 resulting from the effects
of the FERC’s order on System Agreement Service Schedules MSS-1, MSS-2, and MSS-3, and the potential offsetting
cost would be significantly less than that for each of the other Utility operating companies. Entergy provided to the
LPSC an illustrative intra-system bill recalculation as specified by the LPSC for the years 2003, 2004, and 2006, and
the LPSC then filed answering testimony in December 2012. In its testimony the LPSC claims that the damages,
excluding interest, that should be paid by Entergy Arkansas to the other Utility operating company’s customers for
2003, 2004, and 2006 are $42 million to Entergy Gulf States, Inc., $7 million to Entergy Louisiana, $23 million to
Entergy Mississippi, and $4 million to Entergy New Orleans. The FERC staff and certain intervenors filed direct and
answering testimony in February 2013. In April 2013, Entergy filed its rebuttal testimony in that proceeding, including
a revised illustrative re-run of the intra-system bills for the years 2003, 2004, and 2006. The revised calculation
104
E-5 Page 52 of 182
Entergy Corporation and Subsidiaries
Notes to Financial
Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc.
41
determines the re-pricing of the opportunity sales based on consideration of moveable resources only and the removal
of exchange energy received by Entergy Arkansas, which increases the potential cost for Entergy Arkansas over the
three years 2003, 2004, and 2006 by $2.3 million from the potential costs identified in the Utility operating companies’
prior filings in September and October 2012. A hearing was held in May 2013 to quantify the effect of repricing the
opportunity sales in accordance with the FERC’s decision.
In August 2013 the presiding judge issued an initial decision in the calculation proceeding. The initial decision
concludes that the methodology proposed by the LPSC, rather than the methodologies proposed by Entergy or the
FERC Staff, should be used to calculate the payments that Entergy Arkansas is to make to the other Utility operating
companies. The initial decision also concludes that the other System Agreement service schedules should not be
adjusted and that payments by Entergy Arkansas should not be reflected in the rough production cost equalization
bandwidth calculations for the applicable years. The initial decision does recognize that the LPSC’s methodology
would result in an inequitable windfall to the other Utility operating companies and, therefore, concludes that any
payments by Entergy Arkansas should be reduced by 20%. The LPSC, APSC, City Council, and FERC staff filed
briefs on exceptions and/or briefs opposing exceptions. Entergy filed a brief on exceptions requesting that FERC
reverse the initial decision and a brief opposing certain exceptions taken by the LPSC and FERC staff. The FERC’s
review of the initial decision is pending. No payments will be made or received by the Utility operating companies
until the FERC issues an order reviewing the initial decision and Entergy submits a subsequent filing to comply with
that order.
Storm Cost Recovery Filings with Retail Regulators
Entergy Arkansas
Entergy Arkansas December 2012 Winter Storm
In December 2012 a severe winter storm consisting of ice, snow, and high winds caused significant damage
to Entergy Arkansas’s distribution lines, equipment, poles, and other facilities. Total restoration costs for the repair
and/or replacement of Entergy Arkansas’s electrical facilities in areas damaged from the winter storm were $63 million,
including costs recorded as regulatory assets of approximately $22 million. In the Entergy Arkansas 2013 rate case,
the APSC approved inclusion of the construction spending in rate base and approved an increase in the normal storm
cost accrual, which will effectively amortize the regulatory asset over a five-year period.
Entergy Gulf States Louisiana and Entergy Louisiana
Hurricane Isaac
In August 2012, Hurricane Isaac caused extensive damage to portions of Entergy’s service area in Louisiana,
and to a lesser extent in Mississippi and Arkansas. The storm resulted in widespread power outages, significant damage
primarily to distribution infrastructure, and the loss of sales during the power outages. In January 2013, Entergy Gulf
States Louisiana and Entergy Louisiana drew $65 million and $187 million, respectively, from their funded storm
reserve escrow accounts. In April 2013, Entergy Gulf States Louisiana and Entergy Louisiana filed a joint application
with the LPSC relating to Hurricane Isaac system restoration costs. Specifically, Entergy Gulf States Louisiana and
Entergy Louisiana requested that the LPSC determine the amount of such costs that were prudently incurred and are,
thus, eligible for recovery from customers. Including carrying costs and additional storm escrow funds for prior storms,
Entergy Gulf States Louisiana requested an LPSC determination that $73.8 million in system restoration costs were
prudently incurred and Entergy Louisiana requested an LPSC determination that $247.7 million in system restoration
costs were prudently incurred. In May 2013, Entergy Gulf States Louisiana, Entergy Louisiana, and the Louisiana
Utilities Restoration Corporation (LURC), an instrumentality of the State of Louisiana, filed with the LPSC an
application requesting that the LPSC grant financing orders authorizing the financing of Entergy Gulf States Louisiana's
and Entergy Louisiana's storm costs, storm reserves, and issuance costs pursuant to Act 55 of the Louisiana Regular
Session of 2007 (Louisiana Act 55). The LPSC Staff filed direct testimony in September 2013 concluding that Hurricane
105
E-5 Page 53 of 182
Entergy Corporation and Subsidiaries
Notes to Financial Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41
Isaac system restoration costs incurred by Entergy Gulf States Louisiana and Entergy Louisiana were reasonable and
prudent, subject to proposed minor adjustments which totaled approximately 1% of each company’s costs. Following
an evidentiary hearing and recommendations by the ALJ, the LPSC voted in June 2014 to approve a series of orders
which (i) quantify the amount of Hurricane Isaac system restoration costs prudently incurred ($66.5 million for Entergy
Gulf States Louisiana and $224.3 million for Entergy Louisiana); (ii) determine the level of storm reserves to be reestablished ($90 million for Entergy Gulf States Louisiana and $200 million for Entergy Louisiana); (iii) authorize
Entergy Gulf States Louisiana and Entergy Louisiana to utilize Louisiana Act 55 financing for Hurricane Isaac system
restoration costs; and (iv) grant other requested relief associated with storm reserves and Act 55 financing of Hurricane
Isaac system restoration costs. Entergy Gulf States Louisiana committed to pass on to customers a minimum of $6.9
million of customer benefits through annual customer credits of approximately $1.4 million for five years. Entergy
Louisiana committed to pass on to customers a minimum of $23.9 million of customer benefits through annual customer
credits of approximately $4.8 million for five years. Approvals for the Act 55 financings were obtained from the
Louisiana Utilities Restoration Corporation (LURC) and the Louisiana State Bond Commission.
In July 2014, Entergy Gulf States Louisiana issued $110 million of 3.78% Series first mortgage bonds due
April 2025 and used the proceeds to re-establish and replenish its storm damage escrow reserves and for general
corporate purposes. In July 2014, Entergy Louisiana issued $190 million of 3.78% Series first mortgage bonds due
April 2025 and used the proceeds to re-establish and replenish its storm damage escrow reserves and for general
corporate purposes.
In August 2014 the Louisiana Local Government Environmental Facilities and Community Development
Authority (LCDA) issued $71 million in bonds under Act 55 of the Louisiana Legislature. From the $69 million of
bond proceeds loaned by the LCDA to the LURC, the LURC deposited $3 million in a restricted escrow account as a
storm damage reserve for Entergy Gulf States Louisiana and transferred $66 million directly to Entergy Gulf States
Louisiana. Entergy Gulf States Louisiana used the $66 million received from the LURC to acquire 662,426.80 Class
C preferred, non-voting, membership interest units of Entergy Holdings Company LLC, a company wholly-owned
and consolidated by Entergy, that carry a 7.5% annual distribution rate. Distributions are payable quarterly commencing
on September 15, 2014, and the membership interests have a liquidation price of $100 per unit. The preferred
membership interests are callable at the option of Entergy Holdings Company LLC after ten years under the terms of
the LLC agreement. The terms of the membership interests include certain financial covenants to which Entergy
Holdings Company LLC is subject, including the requirement to maintain a net worth of at least $1.75 billion.
In August 2014 the LCDA issued another $243.85 million in bonds under Act 55 of the Louisiana
Legislature. From the $240 million of bond proceeds loaned by the LCDA to the LURC, the LURC deposited $13
million in a restricted escrow account as a storm damage reserve for Entergy Louisiana and transferred $227 million
directly to Entergy Louisiana. Entergy Louisiana used the $227 million received from the LURC to acquire
2,272,725.89 Class C preferred, non-voting, membership interest units of Entergy Holdings Company LLC that carry
a 7.5% annual distribution rate. Distributions are payable quarterly commencing on September 15, 2014, and the
membership interests have a liquidation price of $100 per unit. The preferred membership interests are callable at the
option of Entergy Holdings Company LLC after ten years under the terms of the LLC agreement. The terms of the
membership interests include certain financial covenants to which Entergy Holdings Company LLC is subject, including
the requirement to maintain a net worth of at least $1.75 billion.
Entergy, Entergy Gulf States Louisiana, and Entergy Louisiana do not report the bonds on their balance sheets
because the bonds are the obligation of the LCDA and there is no recourse against Entergy, Entergy Gulf States
Louisiana, or Entergy Louisiana in the event of a bond default. To service the bonds, Entergy Gulf States Louisiana
and Entergy Louisiana collect a system restoration charge on behalf of the LURC, and remit the collections to the bond
indenture trustee. Entergy, Entergy Gulf States Louisiana, and Entergy Louisiana do not report the collections as
revenue because they are merely acting as the billing and collection agents for the state.
106
E-5 Page 54 of 182
Entergy Corporation and Subsidiaries
Notes to Financial
Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc.
41
Hurricane Gustav and Hurricane Ike
In September 2008, Hurricane Gustav and Hurricane Ike caused catastrophic damage to Entergy’s service
territory. Entergy Gulf States Louisiana and Entergy Louisiana filed their Hurricane Gustav and Hurricane Ike storm
cost recovery case with the LPSC in May 2009. In September 2009, Entergy Gulf States Louisiana, Entergy Louisiana,
and the Louisiana Utilities Restoration Corporation (LURC), an instrumentality of the State of Louisiana, filed with
the LPSC an application requesting that the LPSC grant financing orders authorizing the financing of Entergy Gulf
States Louisiana’s and Entergy Louisiana’s storm costs, storm reserves, and issuance costs pursuant to Act 55 of the
Louisiana Regular Session of 2007 (Act 55). Entergy Gulf States Louisiana’s and Entergy Louisiana’s Hurricane
Katrina and Hurricane Rita storm costs were financed primarily by Act 55 financings, as discussed below. Entergy
Gulf States Louisiana and Entergy Louisiana also filed an application requesting LPSC approval for ancillary issues
including the mechanism to flow charges and Act 55 financing savings to customers via a Storm Cost Offset rider.
In December 2009, Entergy Gulf States Louisiana and Entergy Louisiana entered into a stipulation agreement
with the LPSC Staff that provides for total recoverable costs of approximately $234 million for Entergy Gulf States
Louisiana and $394 million for Entergy Louisiana, including carrying costs. Under this stipulation, Entergy Gulf States
Louisiana agrees not to recover $4.4 million and Entergy Louisiana agrees not to recover $7.2 million of their storm
restoration spending. The stipulation also permits replenishing Entergy Gulf States Louisiana’s storm reserve in the
amount of $90 million and Entergy Louisiana’s storm reserve in the amount of $200 million when the Act 55 financings
are accomplished. In March and April 2010, Entergy Gulf States Louisiana, Entergy Louisiana, and other parties to
the proceeding filed with the LPSC an uncontested stipulated settlement that includes these terms and also includes
Entergy Gulf States Louisiana’s and Entergy Louisiana’s proposals under the Act 55 financings, which includes a
commitment to pass on to customers a minimum of $15.5 million and $27.8 million of customer benefits, respectively,
through prospective annual rate reductions of $3.1 million and $5.6 million for five years. A stipulation hearing was
held before the ALJ on April 13, 2010. On April 21, 2010, the LPSC approved the settlement and subsequently issued
two financing orders and one ratemaking order intended to facilitate the implementation of the Act 55 financings. In
June 2010 the Louisiana State Bond Commission approved the Act 55 financings.
In July 2010, the Louisiana Local Government Environmental Facilities and Community Development
Authority (LCDA) issued $468.9 million in bonds under Act 55. From the $462.4 million of bond proceeds loaned
by the LCDA to the LURC, the LURC deposited $200 million in a restricted escrow account as a storm damage reserve
for Entergy Louisiana and transferred $262.4 million directly to Entergy Louisiana. From the bond proceeds received
by Entergy Louisiana from the LURC, Entergy Louisiana used $262.4 million to acquire 2,624,297.11 Class B preferred,
non-voting, membership interest units of Entergy Holdings Company LLC, a company wholly-owned and consolidated
by Entergy, that carry a 9% annual distribution rate. Distributions are payable quarterly commencing on September
15, 2010, and the membership interests have a liquidation price of $100 per unit. The preferred membership interests
are callable at the option of Entergy Holdings Company LLC after ten years under the terms of the LLC agreement. The
terms of the membership interests include certain financial covenants to which Entergy Holdings Company LLC is
subject, including the requirement to maintain a net worth of at least $1 billion.
In July 2010, the LCDA issued another $244.1 million in bonds under Act 55. From the $240.3 million of
bond proceeds loaned by the LCDA to the LURC, the LURC deposited $90 million in a restricted escrow account as
a storm damage reserve for Entergy Gulf States Louisiana and transferred $150.3 million directly to Entergy Gulf
States Louisiana. From the bond proceeds received by Entergy Gulf States Louisiana from the LURC, Entergy Gulf
States Louisiana used $150.3 million to acquire 1,502,643.04 Class B preferred, non-voting, membership interest units
of Entergy Holdings Company LLC, a company wholly-owned and consolidated by Entergy, that carry a 9% annual
distribution rate. Distributions are payable quarterly commencing on September 15, 2010, and the membership interests
have a liquidation price of $100 per unit. The preferred membership interests are callable at the option of Entergy
Holdings Company LLC after ten years under the terms of the LLC agreement. The terms of the membership interests
include certain financial covenants to which Entergy Holdings Company LLC is subject, including the requirement to
maintain a net worth of at least $1 billion.
107
E-5 Page 55 of 182
Entergy Corporation and Subsidiaries
Notes to Financial Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41
Entergy, Entergy Gulf States Louisiana, and Entergy Louisiana do not report the bonds on their balance sheets
because the bonds are the obligation of the LCDA, and there is no recourse against Entergy, Entergy Gulf States
Louisiana or Entergy Louisiana in the event of a bond default. To service the bonds, Entergy Gulf States Louisiana
and Entergy Louisiana collect a system restoration charge on behalf of the LURC, and remit the collections to the bond
indenture trustee. Entergy Gulf States Louisiana and Entergy Louisiana do not report the collections as revenue because
they are merely acting as the billing and collection agents for the state.
Hurricane Katrina and Hurricane Rita
In August and September 2005, Hurricanes Katrina and Rita caused catastrophic damage to large portions of
the Utility’s service territories in Louisiana, Mississippi, and Texas, including the effect of extensive flooding that
resulted from levee breaks in and around the greater New Orleans area. The storms and flooding resulted in widespread
power outages, significant damage to electric distribution, transmission, and generation and gas infrastructure, and the
loss of sales and customers due to mandatory evacuations and the destruction of homes and businesses.
In March 2008, Entergy Gulf States Louisiana, Entergy Louisiana, and the Louisiana Utilities Restoration
Corporation (LURC), an instrumentality of the State of Louisiana, filed at the LPSC an application requesting that the
LPSC grant financing orders authorizing the financing of Entergy Gulf States Louisiana and Entergy Louisiana storm
costs, storm reserves, and issuance costs pursuant to Act 55 of the Louisiana Legislature (Act 55 financings). The Act
55 financings are expected to produce additional customer benefits as compared to traditional securitization. Entergy
Gulf States Louisiana and Entergy Louisiana also filed an application requesting LPSC approval for ancillary issues
including the mechanism to flow charges and savings to customers via a Storm Cost Offset rider. On April 8, 2008,
the Louisiana Public Facilities Authority (LPFA), which is the issuer of the bonds pursuant to the Act 55 financings,
approved requests for the Act 55 financings. On April 10, 2008, Entergy Gulf States Louisiana and Entergy Louisiana
and the LPSC Staff filed with the LPSC an uncontested stipulated settlement that includes Entergy Gulf States Louisiana
and Entergy Louisiana’s proposals under the Act 55 financings, which includes a commitment to pass on to customers
a minimum of $10 million and $30 million of customer benefits, respectively, through prospective annual rate reductions
of $2 million and $6 million for five years. On April 16, 2008, the LPSC approved the settlement and issued two
financing orders and one ratemaking order intended to facilitate implementation of the Act 55 financings. In May 2008
the Louisiana State Bond Commission granted final approval of the Act 55 financings.
In July 2008, the LPFA issued $687.7 million in bonds under the aforementioned Act 55. From the $679
million of bond proceeds loaned by the LPFA to the LURC, the LURC deposited $152 million in a restricted escrow
account as a storm damage reserve for Entergy Louisiana and transferred $527 million directly to Entergy
Louisiana. From the bond proceeds received by Entergy Louisiana from the LURC, Entergy Louisiana invested $545
million, including $17.8 million that was withdrawn from the restricted escrow account as approved by the April 16,
2008 LPSC orders, in exchange for 5,449,861.85 Class A preferred, non-voting, membership interest units of Entergy
Holdings Company LLC, a company wholly-owned and consolidated by Entergy, that carry a 10% annual distribution
rate. Distributions are payable quarterly commencing on September 15, 2008 and have a liquidation price of $100 per
unit. The preferred membership interests are callable at the option of Entergy Holdings Company LLC after ten years
under the terms of the LLC agreement. The terms of the membership interests include certain financial covenants to
which Entergy Holdings Company LLC is subject, including the requirement to maintain a net worth of at least $1
billion.
In August 2008, the LPFA issued $278.4 million in bonds under the aforementioned Act 55. From the $274.7
million of bond proceeds loaned by the LPFA to the LURC, the LURC deposited $87 million in a restricted escrow
account as a storm damage reserve for Entergy Gulf States Louisiana and transferred $187.7 million directly to Entergy
Gulf States Louisiana. From the bond proceeds received by Entergy Gulf States Louisiana from the LURC, Entergy
Gulf States Louisiana invested $189.4 million, including $1.7 million that was withdrawn from the restricted escrow
account as approved by the April 16, 2008 LPSC orders, in exchange for 1,893,918.39 Class A preferred, non-voting,
membership interest units of Entergy Holdings Company LLC that carry a 10% annual distribution rate. Distributions
are payable quarterly commencing on September 15, 2008 and have a liquidation price of $100 per unit. The preferred
108
E-5 Page 56 of 182
Entergy Corporation and Subsidiaries
Notes to Financial
Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc.
41
membership interests are callable at the option of Entergy Holdings Company LLC after ten years under the terms of
the LLC agreement. The terms of the membership interests include certain financial covenants to which Entergy
Holdings Company LLC is subject, including the requirement to maintain a net worth of at least $1 billion. In February
2012, Entergy Gulf States Louisiana sold 500,000 of its Class A preferred membership units in Entergy Holdings
Company LLC, a wholly-owned Entergy subsidiary, to a third party in exchange for $51 million plus accrued but
unpaid distributions on the units. The 500,000 preferred membership units are mandatorily redeemable in January
2112.
Entergy, Entergy Gulf States Louisiana, and Entergy Louisiana do not report the bonds on their balance sheets
because the bonds are the obligation of the LPFA, and there is no recourse against Entergy, Entergy Gulf States Louisiana
or Entergy Louisiana in the event of a bond default. To service the bonds, Entergy Gulf States Louisiana and Entergy
Louisiana collect a system restoration charge on behalf of the LURC, and remit the collections to the bond indenture
trustee. Entergy, Entergy Gulf States Louisiana, and Entergy Louisiana do not report the collections as revenue because
they are merely acting as the billing and collection agent for the state.
Entergy Mississippi
On July 1, 2013, Entergy Mississippi and the Mississippi Public Utilities Staff entered into a joint stipulation,
wherein both parties agreed that approximately $32 million in storm restoration costs incurred in 2011 and 2012 were
prudently incurred and chargeable to the storm damage provision, while approximately $700,000 in prudently incurred
costs were more properly recoverable through the formula rate plan. Entergy Mississippi and the Mississippi Public
Utilities Staff also agreed that the storm damage accrual should be increased from $750,000 per month to $1.75 million
per month. In September 2013 the MPSC approved the joint stipulation with the increase in the storm damage accrual
effective with October 2013 bills. In February 2015, Entergy Mississippi provided notice to the Mississippi Public
Utilities Staff that the storm damage accrual would be set to zero effective with the March 2015 billing cycle as a result
of Entergy Mississippi's storm damage accrual balance exceeding $15 million as of January 31, 2015, but will return
to its current level when the storm damage accrual balance becomes less than $10 million.
Entergy New Orleans
In October 2006, the City Council approved a rate filing settlement agreement that, among other things,
authorized a $75 million storm reserve for damage from future storms, which will be created over a ten-year period
through a storm reserve rider that began in March 2007. These storm reserve funds are held in a restricted escrow
account until needed in response to a storm.
In August 2012, Hurricane Isaac caused extensive damage to Entergy New Orleans’s service area. The storm
resulted in widespread power outages, significant damage primarily to distribution infrastructure, and the loss of sales
during the power outages. Total restoration costs for the repair and/or replacement of Entergy New Orleans’s electric
facilities damaged by Hurricane Isaac were $47.3 million. Entergy New Orleans withdrew $17.4 million from the
storm reserve escrow account to partially offset these costs. In February 2014, Entergy New Orleans made a filing
with the City Council seeking certification of the Hurricane Isaac costs. In January 2015 the City Council issued a
resolution approving the terms of a joint agreement in principle filed by Entergy New Orleans, Entergy Louisiana, and
the City Council Advisors determining, among other things, that Entergy New Orleans’s prudently-incurred storm
recovery costs were $49.3 million, of which $31.7 million, net of reimbursements from the storm reserve escrow
account, remains recoverable from Entergy New Orleans’s electric customers. The resolution also directs Entergy
New Orleans to file an application to securitize the unrecovered Council-approved storm recovery costs of $31.7 million
pursuant to the Louisiana Electric Utility Storm Recovery Securitization Act (Louisiana Act 64). In addition, the
resolution found that it is reasonable for Entergy New Orleans to include in the principal amount of its potential
securitization the costs to fund and replenish Entergy New Orleans’s storm reserve in an amount that achieves the
Council-approved funding level of $75 million. In January 2015, in compliance with that directive, Entergy New
Orleans filed with the City Council an application requesting that the City Council grant a financing order authorizing
the financing of Entergy New Orleans's storm costs, storm reserves, and issuance costs pursuant to Louisiana Act 64.
109
E-5 Page 57 of 182
Entergy Corporation and Subsidiaries
Notes to Financial Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41
New Nuclear Generation Development Costs
Entergy Gulf States Louisiana and Entergy Louisiana
Entergy Gulf States Louisiana and Entergy Louisiana have been developing and are preserving a project option
for new nuclear generation at River Bend. In March 2010, Entergy Gulf States Louisiana and Entergy Louisiana filed
with the LPSC seeking approval to continue the limited development activities necessary to preserve an option to
construct a new unit at River Bend. At its June 2012 meeting the LPSC voted to uphold an ALJ recommendation that
the request of Entergy Gulf States Louisiana and Entergy Louisiana be declined on the basis that the LPSC’s rule on
new nuclear development does not apply to activities to preserve an option to develop and on the further grounds that
the companies improperly engaged in advanced preparation activities prior to certification. The LPSC directed that
Entergy Gulf States Louisiana and Entergy Louisiana be permitted to seek recovery of these costs in their upcoming
rate case filings that were subsequently filed in February 2013. In the resolution of the rate case proceeding the LPSC
provided for an eight-year amortization of costs incurred in connection with the potential development of new nuclear
generation at River Bend, without carrying costs, beginning in December 2014, provided, however, that amortization
of these costs shall not result in a future rate increase. As of December 31, 2014, Entergy Gulf States Louisiana and
Entergy Louisiana each have a regulatory asset of $29.2 million on its balance sheet related to these new nuclear
generation development costs.
Entergy Mississippi
Pursuant to the Mississippi Baseload Act and the Mississippi Public Utilities Act, Entergy Mississippi had
been developing and preserving a project option for new nuclear generation at Grand Gulf Nuclear Station. In October
2010, Entergy Mississippi filed an application with the MPSC requesting that the MPSC determine that it was in the
public interest to preserve the option to construct new nuclear generation at Grand Gulf and that the MPSC approve
the deferral of Entergy Mississippi’s costs incurred to date and in the future related to this project, including the accrual
of AFUDC or similar carrying charges. In October 2011, Entergy Mississippi and the Mississippi Public Utilities Staff
filed with the MPSC a joint stipulation that the MPSC approved in November 2011. The stipulation stated that there
should be a deferral of the $57 million of costs incurred through September 2011 in connection with planning, evaluation,
monitoring, and other and related generation resource development activities for new nuclear generation at Grand Gulf.
In October 2014, Entergy Mississippi and the Mississippi Public Utilities Staff entered into and filed joint
stipulations in Entergy Mississippi’s general rate case proceeding, which are discussed above. In consideration of the
comprehensive terms for settlement in that rate case proceeding, the Mississippi Public Utilities Staff and Entergy
Mississippi agreed that Entergy Mississippi would request consolidation of the new nuclear generation development
costs proceeding with the rate case proceeding for hearing purposes and will not further pursue, except as noted below,
recovery of the costs deferred by MPSC order in the new nuclear generation development docket. The stipulations
state, however, that, if Entergy Mississippi decides to move forward with nuclear development in Mississippi, it can
at that time re-present for consideration by the MPSC only those costs directly associated with the existing early site
permit (ESP), to the extent that the costs are verifiable and prudent and the ESP is still valid and relevant to any such
option pursued. After considering the progress of the new nuclear generation costs proceeding in light of the joint
stipulations, Entergy Mississippi recorded in 2014 a $56.2 million pre-tax charge to recognize that the regulatory asset
associated with new nuclear generation development is no longer probable of recovery. In December 2014 the MPSC
issued an order accepting in their entirety the October 2014 stipulations, including the findings and terms of the
stipulations regarding new nuclear generation development costs.
110
E-5 Page 58 of 182
Entergy Corporation and Subsidiaries
Notes to Financial
Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc.
41
Texas Power Price Lawsuit
In August 2003, a lawsuit was filed in the district court of Chambers County, Texas by Texas residents on
behalf of a purported class of the Texas retail customers of Entergy Gulf States, Inc. who were billed and paid for
electric power from January 1, 1994 to the present. The named defendants include Entergy Corporation, Entergy
Services, Entergy Power, Entergy Power Marketing Corp., and Entergy Arkansas. Entergy Gulf States, Inc. was not
a named defendant, but was alleged to be a co-conspirator. The court granted the request of Entergy Gulf States, Inc.
to intervene in the lawsuit to protect its interests.
Plaintiffs allege that the defendants implemented a “price gouging accounting scheme” to sell to plaintiffs and
similarly situated utility customers higher priced power generated by the defendants while rejecting less expensive
power offered from off-system suppliers. In particular, plaintiffs allege that the defendants manipulated and continue
to manipulate the dispatch of generation so that power is purchased from affiliated expensive resources instead of
buying cheaper off-system power.
Plaintiffs stated in their pleadings that customers in Texas were charged at least $57 million above prevailing
market prices for power. Plaintiffs seek actual, consequential and exemplary damages, costs and attorneys’ fees, and
disgorgement of profits. The plaintiffs’ experts have tendered a report calculating damages in a large range, from $153
million to $972 million in present value, under various scenarios as of the date of the report. The Entergy defendants
have tendered expert reports challenging the assumptions, methodologies, and conclusions of the plaintiffs’ expert
reports.
In March 2012 the state district court found that the case met the requirements to be maintained as a class
action under Texas law. In April 2012 the court entered an order certifying the class. The defendants appealed the
order to the Texas Court of Appeals – First District and oral argument was held in May 2013. In November 2014 the
Texas Court of Appeals - First District reversed the state district court’s class certification order and dismissed the case
holding that the state district court lacked subject matter jurisdiction to address the issues. Plaintiffs filed a motion for
rehearing and a motion for rehearing en banc. The Entergy defendants filed responsive briefings, and the parties are
awaiting rulings by the Court.
NOTE 3. INCOME TAXES (Entergy Corporation, Entergy Arkansas, Entergy Gulf States Louisiana, Entergy
Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)
Income taxes from continuing operations for 2014, 2013, and 2012 for Entergy Corporation and Subsidiaries
consist of the following:
2014
Current:
Federal
Foreign
State
Total
Deferred and non-current - net
Investment tax credit adjustments net
Income tax expense from
continuing operations
2013
(In Thousands)
$90,061
90
(12,637)
77,514
528,326
(16,243)
$589,597
111
$88,291
101
20,584
108,976
126,935
(9,930)
$225,981
2012
($47,851)
143
(41,516)
(89,224)
131,130
(11,051)
$30,855
E-5 Page 59 of 182
Entergy Corporation and Subsidiaries
Notes to Financial Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41
Income taxes for 2014, 2013, and 2012 for Entergy’s Registrant Subsidiaries consist of the following:
2014
Current:
Federal
State
Total
Deferred and noncurrent - net
Investment tax credit
adjustments - net
Income taxes
2013
Current:
Federal
State
Total
Deferred and noncurrent - net
Investment tax credit
adjustments - net
Income taxes
2012
Current:
Federal
State
Total
Deferred and noncurrent - net
Investment tax
credit adjustments net
Income taxes
Entergy
Entergy Gulf States
Arkansas Louisiana
Entergy
Entergy
New
Mississippi Orleans
(In Thousands)
Entergy
Louisiana
($34,258)
(678)
(34,936)
($3,857)
(769)
(4,626)
($41,052)
(422)
(41,474)
$8,103
7,474
15,577
($1,924)
520
(1,404)
119,841
96,446
140,348
42,305
13,952
(1,276)
$83,629
(3,038)
$88,782
(2,604)
$96,270
(2,172)
$55,710
(224)
$12,324
Entergy
Arkansas
Entergy
Gulf States
Louisiana
Entergy
Entergy
New
Mississippi Orleans
(In Thousands)
Entergy
Louisiana
Entergy
Texas
$48,610
4,877
53,487
(2,418)
(1,425)
$49,644
Entergy
Texas
($13,574)
6,122
(7,452)
$12,176
(9,939)
2,237
($30,973)
(5,692)
(36,665)
$2,498
4,849
7,347
$15,017
(1,221)
13,796
$37,199
(843)
36,356
101,253
57,620
121,416
41,150
(11,952)
(4,639)
(2,014)
$91,787
(3,038)
$56,819
(2,874)
$81,877
1,260
$49,757
(225)
$1,619
(1,609)
$30,108
Entergy
Arkansas
$64,069
6,712
70,781
26,042
(2,017)
$94,806
Entergy
Gulf States
Louisiana
Entergy
Louisiana
Entergy
Mississippi
(In Thousands)
($66,081) ($132,999)
9,535
(1,269)
(56,546) (134,268)
112,390
8,463
(3,228)
(3,117)
$52,616 ($128,922)
112
$3,188
(4,425)
(1,237)
Entergy
New
Orleans
Entergy
Texas
($9,484) ($114,677)
(1,617)
4,933
(11,101) (109,744)
System
Energy
$19,908
15,379
35,287
53,501
(5,478)
$83,310
System
Energy
($6,199)
15,845
9,646
60,614
(1,407)
$68,853
System
Energy
($50,491)
(8,544)
(59,035)
59,045
18,586
144,471
137,832
871
$58,679
(245)
$7,240
(1,609)
$33,118
(1,682)
$77,115
E-5 Page 60 of 182
Entergy Corporation and Subsidiaries
Notes to Financial
Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc.
41
Total income taxes for Entergy Corporation and Subsidiaries differ from the amounts computed by applying
the statutory income tax rate to income before income taxes. The reasons for the differences for the years 2014, 2013,
and 2012 are:
2014
Net income attributable to Entergy Corporation
Preferred dividend requirements of subsidiaries
Consolidated net income
Income taxes
Income before income taxes
Computed at statutory rate (35%)
Increases (reductions) in tax resulting from:
State income taxes net of federal income tax effect
Regulatory differences - utility plant items
Equity component of AFUDC
Amortization of investment tax credits
Flow-through / permanent differences
Net-of-tax regulatory liability
New York tax law change
Deferred tax asset on additional depreciation (a)
Termination of business reorganization
Write-off of regulatory asset for income taxes
Capital losses
Provision for uncertain tax positions (b)
Valuation allowance
Other - net
Total income taxes as reported
Effective Income Tax Rate
(a)
(b)
$940,721
19,536
960,257
589,597
$1,549,854
$542,449
44,708
39,321
(21,108)
(12,211)
(18,003)
—
(21,500)
—
—
—
—
32,573
—
3,368
$589,597
38.0%
2013
(In Thousands)
$711,902
18,670
730,572
225,981
$956,553
$334,794
13,599
32,324
(22,356)
(13,535)
(301)
(2,899)
—
—
(27,192)
—
—
(59,249)
(31,573)
2,369
$225,981
23.6%
2012
$846,673
21,690
868,363
30,855
$899,218
$314,726
40,699
35,527
(30,838)
(14,000)
(14,801)
(4,356)
—
(155,300)
—
42,159
(20,188)
(159,957)
—
(2,816)
$30,855
3.4%
See “Income Tax Audits - 2004-2005 IRS Audit” below for discussion of this item.
See “Income Tax Audits - 2008-2009 IRS Audit” below for discussion of the most significant items in
2013 and 2012.
In March 2014, New York enacted legislation that substantially modifies various aspects of New York tax law.
The most significant effect of the legislation for Entergy is the adoption of full water's-edge unitary combined reporting,
meaning that all of Entergy's domestic entities will be included in New York's combined filing group. The effect of
the tax law change resulted in a deferred state income tax reduction of approximately $21.5 million as shown in the
table above.
113
E-5 Page 61 of 182
Entergy Corporation and Subsidiaries
Notes to Financial Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41
Total income taxes for the Registrant Subsidiaries differ from the amounts computed by applying the statutory
income tax rate to income before taxes. The reasons for the differences for the years 2014, 2013, and 2012 are:
2014
Net income
Income taxes
Pretax income
Computed at statutory
rate (35%)
Increases (reductions)
in tax resulting from:
State income taxes
net of federal income
tax effect
Regulatory
differences - utility
plant items
Equity component of
AFUDC
Amortization of
investment tax
credits
Flow-through /
permanent
differences
Non-taxable
dividend income
Provision for
uncertain tax
positions
Other - net
Total income
taxes
Effective Income Tax
Rate
Entergy
Arkansas
Entergy
Gulf States
Louisiana
Entergy
Louisiana
Entergy
Mississippi
Entergy
New
Orleans
Entergy
Texas
System
Energy
(In Thousands)
$74,821
55,710
$130,531
$28,707
12,324
$41,031
$74,804
49,644
$124,448
$96,334
83,310
$179,644
$121,392
83,629
$205,021
$162,491
88,782
$251,273
$283,531
96,270
$379,801
$71,757
$87,946
$132,930
$45,686
$14,361
$43,557
$62,875
9,591
6,532
5,134
5,180
1,643
3,221
6,877
8,653
4,618
2,869
4,448
777
4,165
13,791
(2,533)
(2,602)
(12,010)
(833)
(320)
(1,035)
(1,774)
(1,251)
(3,018)
(2,576)
(260)
(218)
(1,412)
(3,476)
(1,024)
555
(10,590)
(30,665)
—
1,881
613
4,108
989
1,228
384
$83,629
$88,782
$96,270
(5,082)
—
40.8%
799
35.3%
25.3%
114
393
(327)
—
—
—
718
216
405
134
522
233
5,235
109
$55,710
$12,324
$49,644
$83,310
42.7%
(4,458)
30.0%
39.9%
46.4%
E-5 Page 62 of 182
Entergy Corporation and Subsidiaries
Notes to Financial
Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc.
41
2013
Net income
Income taxes
Pretax income
Computed at statutory
rate (35%)
Increases (reductions)
in tax resulting from:
State income taxes
net of federal
income tax effect
Regulatory
differences - utility
plant items
Equity component
of AFUDC
Amortization of
investment tax
credits
Flow-through /
permanent
differences
Net-of-tax
regulatory liability
Termination of
business
reorganization
Non-taxable
dividend income
Provision for
uncertain tax
positions
Other - net
Total income
taxes
Effective Income Tax
Rate
Entergy
Arkansas
Entergy
Gulf States
Louisiana
Entergy
Louisiana
Entergy
Mississippi
(In Thousands)
$252,464
$82,159
81,877
49,757
$334,341
$131,916
Entergy
New
Orleans
Entergy
Texas
System
Energy
$11,683
1,619
$13,302
$57,881
30,108
$87,989
$113,664
68,853
$182,517
$30,796
$63,881
$161,948
91,787
$253,735
$161,662
56,819
$218,481
$88,807
$76,468
$117,019
$46,171
$4,656
10,954
7,719
11,365
4,564
1,012
7,938
4,865
2,140
2,603
453
3,256
11,070
(3,820)
(2,822)
(10,278)
(764)
(322)
(1,626)
(2,724)
(1,989)
(3,018)
(2,846)
(260)
(216)
(1,596)
(3,476)
2,540
2,377
1,269
—
—
(6,753)
—
(6,527)
637
$91,787
36.2%
(2,899)
1,702
—
—
—
(3,834)
(9,612)
(27,341)
—
—
—
(15,557)
18
(3,088)
(326)
1,027
223
$30,108
26.0%
(501)
2,467
(3,619)
$56,819
(4,177)
(4,402)
(897)
370
244
795
144
$81,877
$49,757
$1,619
24.5%
115
37.7%
12.2%
(3,542)
34.2%
5,900
(491)
—
(13)
—
(5,353)
59
$68,853
37.7%
E-5 Page 63 of 182
Entergy Corporation and Subsidiaries
Notes to Financial Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41
2012
Net income
Income taxes
(benefit)
Pretax income
Computed at
statutory rate (35%)
Increases
(reductions)
resulting from:
State income taxes
net of federal
income tax effect
Regulatory
differences - utility
plant items
Equity component
of AFUDC
Amortization of
investment tax
credits
Net-of-tax
regulatory liability
Flow-through /
permanent
differences
Non-taxable
dividend income
Expense (benefit)
of Entergy
Corporation
expenses
Provision for
uncertain tax
positions
Change in
regulatory
recovery
Other - net
Total income
taxes
Effective Income
Tax Rate
Entergy
Arkansas
Entergy
Gulf States
Louisiana
Entergy
Louisiana
Entergy
Mississippi
Entergy
New
Orleans
Entergy
Texas
System
Energy
$152,365
$158,977
(In Thousands)
$281,081
$46,768
94,806
$247,171
52,616
$211,593
(128,922)
$152,159
58,679
$105,447
7,240
$24,305
33,118
$75,089
77,115
$188,981
$86,510
$74,058
$53,256
$36,906
$8,507
$26,281
$66,143
11,282
5,087
1,976
3,944
505
3,115
6,652
6,778
8,472
312
2,619
2,289
3,668
11,389
(2,495)
(3,042)
(12,919)
(1,383)
(276)
(1,587)
(9,136)
(1,992)
(3,204)
(3,089)
(264)
(240)
(1,596)
(3,480)
(4,356)
—
—
—
—
3,427
(7,646)
1,397
—
(9,836)
(27,336)
(19,403)
(17,703)
11,227
8,745
—
(528)
$94,806
38.4%
(553)
(1,762)
$52,616
24.9%
—
(143,583)
7,854
(2,434)
($128,922)
(84.7%)
116
1,961
$17,065
$41,971
$111,866
(4,385)
—
1,585
—
—
—
14,449
2,758
—
870
—
(423)
$58,679
55.6%
(2,095)
1,651
—
177
—
1
$7,240
$33,118
29.8%
44.1%
—
(357)
—
(10,241)
17,966
—
(1,821)
$77,115
40.8%
E-5 Page 64 of 182
Entergy Corporation and Subsidiaries
Notes to Financial
Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc.
41
Significant components of accumulated deferred income taxes and taxes accrued for Entergy Corporation and
Subsidiaries as of December 31, 2014 and 2013 are as follows:
2014
2013
(In Thousands)
Deferred tax liabilities:
Plant basis differences - net
Regulatory assets
Nuclear decommissioning trusts
Pension, net funding
Combined unitary state taxes
Power purchase agreements
Other
Total
Deferred tax assets:
Nuclear decommissioning liabilities
Regulatory liabilities
Pension and other post-employment benefits
Sale and leaseback
Compensation
Accumulated deferred investment tax credit
Provision for allowances and contingencies
Net operating loss carryforwards
Capital losses and miscellaneous tax credits
Valuation allowance
Other
Total
Noncurrent accrued taxes (including unrecognized tax
benefits)
Accumulated deferred income taxes and taxes accrued
($8,128,096)
(922,161)
(1,248,737)
(324,881)
(162,340)
(110,889)
(500,424)
(11,397,528)
($7,941,319)
(922,312)
(1,100,439)
(299,951)
(183,934)
(8,096)
(404,749)
(10,860,800)
874,493
458,230
586,455
153,308
74,692
100,442
160,551
457,758
12,146
(27,387)
58,334
2,909,022
754,828
403,370
469,190
176,119
125,552
106,777
66,026
548,756
13,140
(28,146)
109,606
2,745,218
(606,560)
($9,095,066)
(400,276)
($8,515,858)
Entergy’s estimated tax attributes carryovers and their expiration dates as of December 31, 2014 are as follows:
Carryover Description
Carryover Amount
Year(s) of expiration
$12.3 billion
$10.2 billion
$97.6 million
2023-2034
2015-2033
2015-2034
Federal net operating losses
State net operating losses
Miscellaneous federal and state credits
As a result of the accounting for uncertain tax positions, the amount of the deferred tax assets reflected in the
financial statements is less than the amount of the tax effect of the federal and state net operating loss carryovers, tax
credit carryovers, and other tax attributes reflected on income tax returns. Because it is more likely than not that the
benefit from certain state net operating loss carryovers will not be utilized, a valuation allowance of $21.2 million has
been provided on the deferred tax assets relating to these state net operating loss carryovers.
In the third quarter 2013, Entergy reduced a valuation allowance by $44 million ($28 million net of the federal
income tax effect) that had been provided on a state net operating loss carryover due to the prospective utilization of
such loss carryover.
117
E-5 Page 65 of 182
Entergy Corporation and Subsidiaries
Notes to Financial Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41
Significant components of accumulated deferred income taxes and taxes accrued for the Registrant Subsidiaries
as of December 31, 2014 and 2013 are as follows:
2014
Entergy
Arkansas
Entergy
Gulf States
Louisiana
Entergy
Louisiana
Entergy
Mississippi
Entergy
New
Orleans
Entergy
Texas
System
Energy
(In Thousands)
Deferred tax liabilities:
Plant basis differences
- net
($1,657,503) ($1,233,761) ($1,515,091)
(274,432)
Regulatory assets
(198,662)
(106,287)
Nuclear
(62,551)
decommissioning trusts
(130,524)
(43,611)
(53,190)
Pension, net funding
(93,355)
(46,403)
(500)
Deferred fuel
(82,050)
(3,034)
Power purchase
agreements
(17,073)
(67,083)
—
(75,432)
Other
(33,827)
(8,850)
Total
(2,212,994) (1,509,029) (1,981,196)
Deferred tax assets:
Regulatory liabilities
145,466
70,068
111,533
Nuclear
decommissioning
liabilities
(43,134)
48,815
97,323
Pension and other postemployment benefits
(17,534)
88,606
70,055
Sale and leaseback
—
—
45,136
Accumulated deferred
investment tax credit
14,791
33,941
24,922
Provision for
allowances and
(7,149)
43,512
82,293
contingencies
Unbilled/deferred
(6,463)
revenues
12,322
(18,553)
(483)
Compensation
2,085
641
Net operating loss
carryforwards
105,063
—
241,803
Capital losses and
miscellaneous tax
credits
—
—
—
Other
258
8,102
7,406
Total
212,168
275,132
673,525
Noncurrent accrued
taxes (including
unrecognized tax
(24,278)
benefits)
9,367
(388,230)
Accumulated
deferred income
taxes and taxes
accrued
($1,991,459) ($1,622,127) ($1,331,949)
118
($753,576) ($186,153)
(30,114)
—
($771,135) ($668,779)
(202,402) (110,087)
—
(27,861)
(5,303)
—
(13,285)
(407)
—
(25,616)
2,129
(11,423)
(826,148)
13
(11,500)
(211,332)
847
(22,546)
(1,018,807)
2,045
7,214
29,580
4,079
—
—
—
(7,288)
(7,504)
(74,063)
(23,440)
(120)
—
(19,802)
(896,291)
90,290
(62,571)
(15,053)
(1,413)
—
—
—
108,172
2,436
332
5,158
18,862
19,590
10,986
8,017
133
12,956
(846)
3,395
475
11,573
4,155
—
—
—
—
—
—
3,504
5,887
43,453
—
2,891
40,155
—
3,850
21,779
—
2,000
155,473
(12,481)
(19,502)
(48,921)
(81,528)
($795,176) ($190,679) ($1,045,949) ($822,346)
E-5 Page 66 of 182
Entergy Corporation and Subsidiaries
Notes to Financial
Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc.
41
2013
Entergy
Arkansas
Entergy
Gulf States
Louisiana
Entergy
Louisiana
Entergy
Mississippi
Entergy
New
Orleans
Entergy
Texas
System
Energy
(In Thousands)
Deferred tax liabilities:
Plant basis
differences - net
Regulatory assets
Nuclear
decommissioning
trusts
Pension, net
funding
Deferred fuel
Power purchase
agreements
Other
Total
Deferred tax assets:
Regulatory
liabilities
Nuclear
decommissioning
liabilities
Pension and other
post-employment
benefits
Sale and leaseback
Accumulated
deferred investment
tax credit
Provision for
allowances and
contingencies
Unbilled/deferred
revenues
Compensation
Net operating loss
carryforwards
Capital losses and
miscellaneous tax
credits
Other
Total
Noncurrent accrued
taxes (including
unrecognized tax
benefits)
Accumulated
deferred income
taxes and taxes
accrued
($1,613,195) ($1,259,173) ($1,347,534)
(255,068)
(212,339)
(102,362)
($727,545) ($196,726)
(33,277)
—
(110,004)
(32,574)
(50,248)
(79,589)
(26,946)
(45,342)
(4,361)
(50,630)
(512)
(24,392)
(21,823)
(11,606)
(7,053)
(62,046)
(2,111,172)
(20,234)
(25,694)
(1,489,740)
—
(69,194)
(1,773,186)
—
(10,732)
(817,769)
13
(13,446)
(221,702)
—
—
63
($759,263) ($698,151)
(205,402) (113,849)
(58,308)
—
(23,598)
(470)
(21,187)
(129)
1,269
(58,963)
(1,046,427)
—
(8,969)
(900,593)
120,966
60,176
94,019
8,357
35,764
7,952
(64,571)
49,439
92,206
—
—
—
(12,132)
—
73,136
—
62,999
52,054
(1,345)
—
1,532
—
15,281
35,297
25,913
3,263
12,313
14,784
3,347
37,825
7,131
(22,340)
4,701
76,135
(71,898)
(13,417)
(2,073)
—
124,065
416
5,651
20,956
13,066
8,535
5,980
—
3,026
3,470
6,791
1,778
4,226
1,696
10,655
6,774
—
822
85,875
—
230,592
19,400
—
—
—
—
3,682
206,370
—
4,939
220,132
—
4,148
571,774
6,173
4,224
61,707
—
2,930
55,099
—
3,807
27,402
—
2,001
150,008
22,565
(279,269)
25,512
(6,290)
(5,015)
(37,777)
10,302
($1,882,237) ($1,548,877) ($1,175,900)
119
($762,352) ($171,618) ($1,056,802) ($740,283)
E-5 Page 67 of 182
Entergy Corporation and Subsidiaries
Notes to Financial Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41
The Registrant Subsidiaries’ estimated tax attributes carryovers and their expiration dates as of December 31,
2014 are as follows:
Entergy
Arkansas
Entergy
Gulf States
Louisiana
Entergy
Louisiana
Entergy
Mississippi
Entergy
New
Orleans
Entergy
Texas
Federal net operating
losses
Year(s) of expiration
$1.3 billion
2029-2034
$151 million
2029-2032
$2.1 billion
2029-2034
—
N/A
$55 million
2031-2034
—
N/A
State net operating
losses
Year(s) of expiration
$235 million
2015-2028
$580 million
2024-2027
$3 billion
2024-2029
—
N/A
$24 million
2026-2029
—
N/A
Misc. federal credits
Year(s) of expiration
$1 million
2029-2033
$6 million
2029-2033
$13 million
2026-2033
$1 million
2029-2033
—
N/A
—
N/A
$9.5 million
2015-2019
—
N/A
State credits
Year(s) of expiration
—
N/A
—
N/A
—
N/A
System
Energy
$392 million
2030-2032
—
N/A
$10 million
2029-2033
$3.4 million $15.7 million
2026
2015-2019
As a result of the accounting for uncertain tax positions, the amount of the deferred tax assets reflected in the
financial statements is less than the amount of the tax effect of the federal and state net operating loss carryovers and
tax credit carryovers.
Unrecognized tax benefits
Accounting standards establish a “more-likely-than-not” recognition threshold that must be met before a tax
benefit can be recognized in the financial statements. If a tax deduction is taken on a tax return, but does not meet the
more-likely-than-not recognition threshold, an increase in income tax liability, above what is payable on the tax return,
is required to be recorded. A reconciliation of Entergy’s beginning and ending amount of unrecognized tax benefits
is as follows:
2014
Gross balance at January 1
Additions based on tax positions related to the current
year
Additions for tax positions of prior years
Reductions for tax positions of prior years
Settlements
Lapse of statute of limitations
Gross balance at December 31
Offsets to gross unrecognized tax benefits:
Credit and loss carryovers
Unrecognized tax benefits net of unused tax attributes
and payments (a)
(a)
2013
(In Thousands)
$4,593,224
$4,170,403
2012
$4,387,780
348,543
11,637
(213,401)
—
(3,218)
4,736,785
162,338
410,108
(103,360)
(43,620)
(2,645)
4,593,224
163,612
1,517,797
(476,873)
(1,421,913)
—
4,170,403
(4,295,643)
(4,400,498)
(4,022,535)
$441,142
$192,726
$147,868
Potential tax liability above what is payable on tax returns
120
E-5 Page 68 of 182
Entergy Corporation and Subsidiaries
Notes to Financial
Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc.
41
The balances of unrecognized tax benefits include $516 million, $176 million, and $203 million as of
December 31, 2014, 2013, and 2012, respectively, which, if recognized, would lower the effective income tax
rates. Because of the effect of deferred tax accounting, the remaining balances of unrecognized tax benefits of $4.221
billion, $4.417 billion, and $3.968 billion as of December 31, 2014, 2013, and 2012, respectively, if disallowed, would
not affect the annual effective income tax rate but would accelerate the payment of cash to the taxing authority to an
earlier period.
Entergy accrues interest expense, if any, related to unrecognized tax benefits in income tax expense. Entergy’s
December 31, 2014, 2013, and 2012 accrued balance for the possible payment of interest is approximately $127 million,
$96.4 million, and $146.3 million, respectively.
A reconciliation of the Registrant Subsidiaries’ beginning and ending amount of unrecognized tax benefits
for 2014, 2013, and 2012 is as follows:
2014
Gross balance at
January 1, 2014
Additions based on
tax positions related
to the current year
Additions for tax
positions of prior
years
Reductions for tax
positions of prior
years
Settlements
Gross balance at
December 31, 2014
Offsets to gross
unrecognized tax
benefits:
Loss carryovers
Unrecognized tax
benefits net of
unused tax
attributes and
payments
Entergy
Arkansas
Entergy
Entergy
Gulf States Entergy
Entergy
New
Louisiana Louisiana Mississippi Orleans
(In Thousands)
Entergy
Texas
System
Energy
$347,713
$465,075
$611,605
$16,186
$51,679
$13,017
$265,185
14,511
55,053
96,196
3,928
2,235
4,225
2,744
1,767
5,204
1,720
319
37
303
566
(1,079)
—
(7,995)
—
(20,929)
—
(289)
—
(188)
—
(267)
(14)
362,912
517,337
688,592
20,144
53,763
(361,043)
(89,448)
(650,540)
(6,992)
(20,735)
$1,869
$427,889
$38,052
121
$13,152
$33,028
17,264
(241)
$17,023
(10,253)
—
258,242
(163,124)
$95,118
E-5 Page 69 of 182
Entergy Corporation and Subsidiaries
Notes to Financial Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41
2013
Gross balance at
January 1, 2013
Additions based on
tax positions related
to the current year
Additions for tax
positions of prior
years
Reductions for tax
positions of prior
years
Settlements
Gross balance at
December 31, 2013
Offsets to gross
unrecognized tax
benefits:
Loss carryovers
Unrecognized tax
benefits net of
unused tax attributes
and payments
Entergy
Arkansas
Entergy
Gulf States Entergy
Louisiana Louisiana
Entergy
Mississippi
(In Thousands)
Entergy
New
Orleans
Entergy
Texas
System
Energy
$344,669
$465,721
$536,673
$16,841
$52,018
$13,954
$260,346
6,427
7,276
10,611
957
583
2,170
4,170
1,228
7,189
118,025
401
3,506
587
8,391
(3,943)
(668)
(15,045)
(66)
(38,428)
(15,276)
(1,941)
(72)
(962)
(3,466)
(4,186)
492
347,713
465,075
611,605
16,186
51,679
13,017
(345,674)
(136,151)
(611,605)
(16,186)
(22,078)
$2,039
$328,924
$—
122
$—
$29,601
(266)
$12,751
(967)
(6,755)
265,185
(225,286)
$39,899
E-5 Page 70 of 182
Entergy Corporation and Subsidiaries
Notes to Financial
Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc.
41
Entergy
Arkansas
2012
Gross balance at
January 1, 2012
Additions based on
tax positions related
to the current year
Additions for tax
positions of prior
years
Reductions for tax
positions of prior
years
Settlements
Gross balance at
December 31, 2012
Offsets to gross
unrecognized tax
benefits:
Loss carryovers
Unrecognized tax
benefits net of
unused tax attributes
and payments
Entergy
Gulf States Entergy
Louisiana Louisiana
Entergy
Mississippi
(In Thousands)
Entergy
New
Orleans
Entergy
Texas
System
Energy
$335,493
$390,493
$446,187
$11,052
$56,052
$19,225
$281,183
10,409
8,974
67,721
8,401
497
1,656
8,715
429,232
392,548
331,432
4,057
445
4,834
271,172
(39,534)
(390,931)
(50,518)
(275,776)
(169,465)
(139,202)
(5,703)
(966)
(2,506)
(2,470)
(11,649)
(112)
(20,934)
(279,790)
344,669
465,721
536,673
16,841
52,018
13,954
260,346
(342,127)
(160,955)
(536,673)
(16,841)
(35,511)
(1,593)
(249,424)
$2,542
$304,766
$—
$—
$16,507
$12,361
$10,922
The Registrant Subsidiaries’ balances of unrecognized tax benefits included amounts which, if recognized,
would have reduced income tax expense as follows:
2014
Entergy Arkansas
Entergy Gulf States Louisiana
Entergy Louisiana
Entergy Mississippi
Entergy New Orleans
Entergy Texas
System Energy
$2.6
$91.9
$175.4
$3.9
$50.7
$10.5
$3.7
123
December 31,
2013
(In Millions)
$0.6
$44.0
$87.9
$3.9
$—
$10.1
$3.3
2012
$0.6
$44.0
$92.4
$3.9
$—
$8.6
$3.5
E-5 Page 71 of 182
Entergy Corporation and Subsidiaries
Notes to Financial Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41
The Registrant Subsidiaries accrue interest and penalties related to unrecognized tax benefits in income tax
expense. Penalties have not been accrued. Accrued balances for the possible payment of interest are as follows:
2014
Entergy Arkansas
Entergy Gulf States Louisiana
Entergy Louisiana
Entergy Mississippi
Entergy New Orleans
Entergy Texas
System Energy
$17.0
$21.0
$1.2
$2.8
$1.3
$1.0
$23.8
December 31,
2013
(In Millions)
$15.2
$17.0
$1.0
$2.1
$0.9
$0.8
$19.0
2012
$21.8
$33.1
$0.9
$2.4
$0.1
$0.7
$33.2
Income Tax Litigation
In October 2010 the U.S. Tax Court entered a decision in favor of Entergy regarding the ability to credit the
U.K. Windfall Tax against U.S. income tax as a foreign tax credit. The U.K. Windfall Tax relates to Entergy’s former
investment in London Electricity.
The IRS filed an appeal of the U.K. Windfall Tax decision with the U.S. Court of Appeals for the Fifth Circuit
in December 2010. Oral arguments were heard in November 2011. In June 2012 the U.S. Court of Appeals for the
Fifth Circuit unanimously affirmed the U.S. Tax Court decision. As a result of this decision, Entergy reversed its
liability for uncertain tax positions associated with this issue. On September 4, 2012, the U.S. Solicitor General, on
behalf of the Commissioner of Internal Revenue, petitioned the U.S. Supreme Court for a writ of certiorari to review
the Fifth Circuit judgment.
Concurrent with the Tax Court’s issuance of a favorable decision regarding the above issues, the Tax Court
issued a favorable decision in a separate proceeding, PPL Corp. v. Commissioner, regarding the creditability of the
U.K. Windfall Tax. The IRS appealed the PPL decision to the United States Court of Appeals for the Third Circuit. In
December 2011 the Third Circuit reversed the Tax Court’s holding in PPL Corp. v. Commissioner, stating that the U.K.
tax was not eligible for the foreign tax credit. PPL Corp. petitioned the U.S. Supreme Court for a writ of certiorari to
review the U.S. Court of Appeals for the Third Circuit decision. On October 29, 2012, the U.S. Supreme Court granted
PPL Corp.’s petition for certiorari. The Solicitor General’s petition for writ of certiorari in Entergy’s case was held
pending the disposition of the PPL case.
On May 20, 2013, the U.S. Supreme Court issued a unanimous decision in PPL’s favor, holding that the U.K.
Windfall Tax is a creditable tax for U.S. federal income tax purposes. On May 28, 2013, the Supreme Court denied
the petition for certiorari filed by the Commissioner of Internal Revenue in Entergy’s U.K. Windfall Tax case, allowing
the decision in Entergy’s favor from the United States Court of Appeals for the Fifth Circuit to become final.
Income Tax Audits
Entergy and its subsidiaries file U.S. federal and various state and foreign income tax returns. IRS examinations
are substantially completed for years before 2009. All state taxing authorities’ examinations are completed for years
before 2005.
2004-2005 IRS Audit
In June 2009, Entergy filed a formal protest with the IRS Appeals Division indicating disagreement with certain
issues contained in the 2004-2005 Revenue Agent’s Report (RAR). The most significant issue disputed was the
124
E-5 Page 72 of 182
Entergy Corporation and Subsidiaries
Notes to Financial
Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc.
41
inclusion of nuclear decommissioning liabilities in cost of goods sold for the nuclear power plants owned by the Utility
resulting from an Application for Change in Accounting Method for tax purposes (the “2004 CAM”).
During the fourth quarter 2012, Entergy settled the position relating to the 2004 CAM. Under the settlement
Entergy conceded its tax position, resulting in an increase in taxable income of approximately $2.97 billion for the tax
years 2004 - 2007. The settlement provides that Entergy Louisiana is entitled to additional tax depreciation of
approximately $547 million for years 2006 and beyond. The deferred tax asset net of interest charges associated with
the settlement is $155 million for Entergy. There was a related increase to Entergy Louisiana’s member’s equity
account.
2008-2009 IRS Audit
In the third quarter 2008, Entergy Louisiana and Entergy Gulf States Louisiana received $679 million and
$274.7 million, respectively, from the Louisiana Utilities Restoration Corporation (“LURC”). These receipts from
LURC were from the proceeds of a Louisiana Act 55 financing of the costs incurred to restore service following
Hurricane Katrina and Hurricane Rita. See Note 2 to the financial statements for further details regarding the financings.
In June 2012, Entergy effectively settled the tax treatment of the storm restoration, which resulted in an increase
to 2008 taxable income of $129 million for Entergy Louisiana and $104 million for Entergy Gulf States Louisiana and
a reduction of income tax expense of $172 million, including $143 million for Entergy Louisiana and $20 million for
Entergy Gulf States Louisiana. Under the terms of an LPSC-approved settlement related to the Louisiana Act 55
financings, Entergy Louisiana and Entergy Gulf States Louisiana recorded, respectively, a $137 million ($84 million
net-of-tax) and a $28 million ($17 million net-of-tax) regulatory charge and a corresponding regulatory liability to
reflect their obligations to customers with respect to the settlement.
In the fourth quarter 2009, Entergy filed Applications for Change in Accounting Method (the “2009 CAM”)
for tax purposes with the IRS for certain costs under Section 263A of the Internal Revenue Code. In the Applications,
Entergy proposed to treat the nuclear decommissioning liability associated with the operation of its nuclear power
plants as a production cost properly includable in cost of goods sold. The effect of the 2009 CAM was a $5.7 billion
reduction in 2009 taxable income. The 2009 CAM was adjusted to $9.3 billion in 2012.
In the fourth quarter 2012 the IRS disallowed the reduction to 2009 taxable income related to the 2009 CAM. In
the third quarter 2013, the Internal Revenue Service issued its RAR for the tax years 2008-2009. As a result of the
issuance of this RAR, Entergy and the IRS resolved all of the 2008-2009 issues described above except for the 2009
CAM. Entergy disagrees with the IRS’s disallowance of the 2009 CAM and filed a protest with the IRS Appeals
Division on October 24, 2013. Two conferences with the Appeals Division have taken place during 2014. The resolution
of this issue is in process. The issuance of the RAR by the IRS effectively settled all other issues, which resulted in
an adjustment to the provision for uncertain tax positions.
Other Tax Matters
Entergy regularly negotiates with the IRS to achieve settlements. The resolution of the nuclear
decommissioning liability audit issue, discussed above, could result in significant changes to the amounts of
unrecognized tax benefits in the next twelve months.
In September 2013 the U.S. Treasury Department and the IRS issued final regulations that provide guidance
on the deductibility and capitalization of costs incurred associated with tangible property. Entergy and the Registrant
Subsidiaries filed with the IRS an automatic application for change in accounting method which is in compliance with
the final regulations and the safe harbor provisions of the relevant IRS Revenue Procedures. Entergy estimates that
the effect of this accounting method change will result in a net increase to Entergy’s taxable income of approximately
$548 million, which will be recognized over a four year period beginning with the tax year ended 2014. The adoption
of the final regulations and safe harbor method results in approximate changes in the Registrant Subsidiaries taxable
125
E-5 Page 73 of 182
Entergy Corporation and Subsidiaries
Notes to Financial Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41
income as follows: an increase of $157 million for Entergy Arkansas, an increase of $42 million for Entergy Gulf States
Louisiana, an increase of $49 million for Entergy Louisiana, an increase of $23 million for Entergy Mississippi, an
increase of $169 million for Entergy Texas, a decrease of $11 million for Entergy New Orleans, and an increase of $34
million for System Energy.
In March 2013, Entergy Louisiana distributed to its parent, Entergy Louisiana Holdings, Inc., Louisiana income
tax credits of $20.6 million, which resulted in a decrease in Entergy Louisiana’s member’s equity account.
The Tax Increase Prevention Act of 2014 was enacted in December 2014. The most significant provisions
affecting Entergy and the Registrant Subsidiaries were a one-year extension of 50% bonus depreciation and the research
and experimentation tax credit. These provisions do not result in an immediate cash flow benefit but will result in cash
flow benefits for Entergy in a future period.
NOTE 4. REVOLVING CREDIT FACILITIES, LINES OF CREDIT, AND SHORT-TERM BORROWINGS
(Entergy Corporation, Entergy Arkansas, Entergy Gulf States Louisiana, Entergy Louisiana, Entergy
Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)
Entergy Corporation has in place a credit facility that has a borrowing capacity of $3.5 billion and expires in
March 2019. Entergy Corporation also has the ability to issue letters of credit against 50% of the total borrowing
capacity of the credit facility. The commitment fee is currently 0.275% of the undrawn commitment
amount. Commitment fees and interest rates on loans under the credit facility can fluctuate depending on the senior
unsecured debt ratings of Entergy Corporation. The weighted average interest rate for the year ended December 31,
2014 was 1.93% on the drawn portion of the facility. Following is a summary of the borrowings outstanding and
capacity available under the facility as of December 31, 2014.
Capacity (a)
$3,500
Letters
Borrowings
of Credit
(In Millions)
$695
$9
Capacity
Available
$2,796
Entergy Corporation’s facility requires it to maintain a consolidated debt ratio of 65% or less of its total
capitalization. Entergy is in compliance with this covenant. If Entergy fails to meet this ratio, or if Entergy Corporation
or one of the Utility operating companies (except Entergy New Orleans) defaults on other indebtedness or is in
bankruptcy or insolvency proceedings, an acceleration of the facility maturity date may occur.
Entergy Corporation has a commercial paper program with a Board-approved program limit of up to $1.5
billion. At December 31, 2014, Entergy Corporation had $484 million of commercial paper outstanding. The
weighted-average interest rate for the year ended December 31, 2014 was 0.88%.
126
E-5 Page 74 of 182
Entergy Corporation and Subsidiaries
Notes to Financial
Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc.
41
Entergy Arkansas, Entergy Gulf States Louisiana, Entergy Louisiana, Entergy Mississippi, Entergy New
Orleans, and Entergy Texas each had credit facilities available as of December 31, 2014 as follows:
Company
Entergy Arkansas
Entergy Arkansas
Entergy Gulf States Louisiana
Entergy Louisiana
Entergy Mississippi
Entergy Mississippi
Entergy Mississippi
Entergy Mississippi
Entergy New Orleans
Entergy Texas
(a)
(b)
(c)
(d)
(e)
(f)
(g)
Expiration
Date
April 2015
March 2019
March 2019
March 2019
May 2015
May 2015
May 2015
May 2015
November 2015
March 2019
Amount of
Facility
$20 million (b)
$150 million (c)
$150 million (d)
$200 million (e)
$10 million (f)
$35 million (f)
$20 million (f)
$37.5 million (f)
$25 million
$150 million (g)
Interest Rate
(a)
1.67%
1.67%
1.42%
1.42%
1.67%
1.67%
1.67%
1.67%
1.92%
1.67%
Amount Drawn
as of
December 31,
2014
—
—
—
—
—
—
—
—
—
—
The interest rate is the rate as of December 31, 2014 that would be applied to outstanding borrowings under
the facility.
Borrowings under this Entergy Arkansas credit facility may be secured by a security interest in its accounts
receivable at Entergy Arkansas’s option.
The credit facility allows Entergy Arkansas to issue letters of credit against 50% of the borrowing capacity of
the facility. As of December 31, 2014, no letters of credit were outstanding.
The credit facility allows Entergy Gulf States Louisiana to issue letters of credit against 50% of the borrowing
capacity of the facility. As of December 31, 2014, no letters of credit were outstanding.
The credit facility allows Entergy Louisiana to issue letters of credit against 50% of the borrowing capacity
of the facility. As of December 31, 2014, no letters of credit were outstanding.
Borrowings under the Entergy Mississippi credit facilities may be secured by a security interest in its accounts
receivable at Entergy Mississippi’s option.
The credit facility allows Entergy Texas to issue letters of credit against 50% of the borrowing capacity of the
facility. As of December 31, 2014, $1.3 million in letters of credit were outstanding.
The commitment fees on the credit facilities range from 0.125% to 0.275% of the undrawn commitment amount. Each
of the credit facilities requires the Registrant Subsidiary borrower to maintain a debt ratio of 65% or less of its total
capitalization. Each Registrant Subsidiary is in compliance with this covenant.
127
E-5 Page 75 of 182
Entergy Corporation and Subsidiaries
Notes to Financial Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41
In addition, Entergy Arkansas, Entergy Gulf States Louisiana, Entergy Louisiana, Entergy Mississippi, Entergy
New Orleans, and Entergy Texas each entered into one or more uncommitted standby letter of credit facilities as a
means to post collateral to support its obligations related to MISO. Following is a summary of the uncommitted standby
letter of credit facilities as of December 31, 2014:
Company
Entergy Arkansas
Entergy Gulf States Louisiana
Entergy Louisiana
Entergy Mississippi
Entergy Mississippi
Entergy New Orleans
Entergy Texas
Amount of
Uncommitted
Facility
$25 million
$75 million
$50 million
$40 million
$40 million
$15 million
$50 million
Letter of
Credit Fee
0.70%
0.70%
0.70%
0.70%
1.50%
0.75%
0.70%
Letters of Credit
Issued as of
December 31, 2014
$2.0 million
$27.9 million
$4.7 million
$14.4 million
—
$8.1 million
$24.5 million
The short-term borrowings of the Registrant Subsidiaries are limited to amounts authorized by the FERC. The
current FERC-authorized limits are effective through October 31, 2015. In addition to borrowings from commercial
banks, these companies are authorized under a FERC order to borrow from the Entergy System money pool. The
money pool is an inter-company borrowing arrangement designed to reduce the Utility subsidiaries’ dependence on
external short-term borrowings. Borrowings from the money pool and external short-term borrowings combined may
not exceed the FERC-authorized limits. The following are the FERC-authorized limits for short-term borrowings and
the outstanding short-term borrowings as of December 31, 2014 (aggregating both money pool and external short-term
borrowings) for the Registrant Subsidiaries:
Authorized
Borrowings
(In Millions)
$250
—
$200
—
$250
—
$175
—
$100
—
$200
—
$200
—
Entergy Arkansas
Entergy Gulf States Louisiana
Entergy Louisiana
Entergy Mississippi
Entergy New Orleans
Entergy Texas
System Energy
Entergy Nuclear Vermont Yankee Credit Facilities
In January 2015, Entergy Nuclear Vermont Yankee entered into a credit facility guaranteed by Entergy
Corporation with a borrowing capacity of $60 million which expires in January 2018. Entergy Nuclear Vermont Yankee
does not have the ability to issue letters of credit against this facility. This facility provides working capital to Entergy
Nuclear Vermont Yankee for general business purposes including, without limitation, the decommissioning of Entergy
Nuclear Vermont Yankee’s nuclear facilities. The commitment fee is currently 0.25% of the undrawn commitment
amount. The weighted average interest rate that would have applied to any outstanding borrowings at the time Entergy
Nuclear Vermont Yankee entered into the facility was 1.92% on the drawn portion of the facility.
Also in January 2015, Entergy Nuclear Vermont Yankee entered into an uncommitted credit facility guaranteed
by Entergy Corporation with a borrowing capacity of $85 million which expires in January 2018. Entergy Nuclear
Vermont Yankee does not have the ability to issue letters of credit against this facility. This facility provides an additional
funding source to Entergy Nuclear Vermont Yankee for general business purposes including, without limitation, the
decommissioning of Entergy Nuclear Vermont Yankee’s nuclear facilities. The weighted average interest rate that
128
E-5 Page 76 of 182
Entergy Corporation and Subsidiaries
Notes to Financial
Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc.
41
would have applied to any outstanding borrowings at the time Entergy Nuclear Vermont Yankee entered into the facility
was 1.92% on the drawn portion of the facility.
Variable Interest Entities (Entergy Corporation, Entergy Arkansas, Entergy Gulf States Louisiana, Entergy
Louisiana, and System Energy)
See Note 18 to the financial statements for a discussion of the consolidation of the nuclear fuel company
variable interest entities (VIE). The nuclear fuel company variable interest entities have credit facilities and also issue
commercial paper to finance the acquisition and ownership of nuclear fuel as follows as of December 31, 2014:
(a)
Company
Expiration
Date
Entergy Arkansas VIE
Entergy Gulf States Louisiana VIE
Entergy Louisiana VIE
System Energy VIE
June 2016
June 2016
June 2016
June 2016
Weighted
Average
Interest
Amount
Rate on
of
Borrowings
Facility
(a)
(Dollars in Millions)
$85
1.61%
$100
n/a
$90
1.54%
$125
1.68%
Amount
Outstanding
as of
December 31,
2014
$48.0
$—
$46.0
$20.4
Includes letter of credit fees and bank fronting fees on commercial paper issuances by the nuclear fuel company
variable interest entities for Entergy Arkansas, Entergy Louisiana, and System Energy. The nuclear fuel
company variable interest entity for Entergy Gulf States Louisiana does not issue commercial paper, but borrows
directly on its bank credit facility.
Amounts outstanding on the Entergy Gulf States Louisiana nuclear fuel company variable interest entity’s
credit facility, if any, are included in long-term debt on its balance sheet and commercial paper outstanding for the
other nuclear fuel company variable interest entities is classified as a current liability on the respective balance
sheets. The commitment fees on the credit facilities are 0.10% of the undrawn commitment amount for the Entergy
Louisiana and Entergy Gulf States Louisiana VIEs and 0.125% of the undrawn commitment amount for the Entergy
Arkansas and System Energy VIEs. Each credit facility requires the respective lessee of nuclear fuel (Entergy Arkansas,
Entergy Gulf States Louisiana, Entergy Louisiana, or Entergy Corporation as guarantor for System Energy) to maintain
a consolidated debt ratio of 70% or less of its total capitalization.
129
E-5 Page 77 of 182
Entergy Corporation and Subsidiaries
Notes to Financial Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41
The nuclear fuel company variable interest entities had notes payable that are included in debt on the respective
balance sheets as of December 31, 2014 as follows:
Company
Entergy Arkansas VIE
Entergy Arkansas VIE
Entergy Arkansas VIE
Entergy Gulf States Louisiana VIE
Entergy Gulf States Louisiana VIE
Entergy Louisiana VIE
Entergy Louisiana VIE
Entergy Louisiana VIE
System Energy VIE
System Energy VIE
System Energy VIE
Description
3.23% Series J due July 2016
2.62% Series K due December 2017
3.65% Series L due July 2021
3.25% Series Q due July 2017
3.38% Series R due August 2020
3.30% Series F due March 2016
3.25% Series G due July 2017
3.92% Series H due February 2021
5.33% Series G due April 2015
4.02% Series H due February 2017
3.78% Series I due October 2018
Amount
$55 million
$60 million
$90 million
$75 million
$70 million
$20 million
$25 million
$40 million
$60 million
$50 million
$85 million
In accordance with regulatory treatment, interest on the nuclear fuel company variable interest entities’ credit
facilities, commercial paper, and long-term notes payable is reported in fuel expense.
Entergy Arkansas, Entergy Gulf States Louisiana, Entergy Louisiana, and System Energy each have obtained
long-term financing authorizations from the FERC that extend through October 2015 for issuances by its nuclear fuel
company variable interest entity.
130
E-5 Page 78 of 182
Entergy Corporation and Subsidiaries
Notes to Financial
Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc.
41
NOTE 5. LONG - TERM DEBT (Entergy Corporation, Entergy Arkansas, Entergy Gulf States Louisiana,
Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)
Long-term debt for Entergy Corporation and subsidiaries as of December 31, 2014 and 2013 consisted of:
Type of Debt and Maturity
Mortgage Bonds
2014-2019
2020-2024
2025-2029
2032-2039
2040-2064
Governmental Bonds (a)
2015-2017
2021-2022
2028-2030
Securitization Bonds
2016-2023
Variable Interest Entities Notes
Payable (Note 4)
2014-2021
Entergy Corporation Notes
due September 2015
due January 2017
due September 2020
Note Payable to NYPA
5 Year Credit Facility (Note 4)
Long-term DOE Obligation (c)
Waterford 3 Lease Obligation (d)
Grand Gulf Lease Obligation (d)
Term Loan - Entergy Arkansas
Unamortized Premium and
Discount - Net
Other
Total Long-Term Debt
Less Amount Due Within One
Year
Long-Term Debt Excluding
Amount Due Within One Year
Fair Value of Long-Term Debt (e)
(a)
Weighted
Average Interest
Rate December 31,
2014
Interest Rate Ranges at
December 31,
2014
2013
Outstanding at
December 31,
2014
2013
(In Thousands)
6.49%
4.18%
4.54%
6.16%
5.28%
3.25%-7.13%
3.05%-5.60%
3.78%-5.66%
5.90%-6.38%
4.70%-6.20%
1.88%-7.13%
3.05%-5.60%
4.44%-5.66%
5.90%-7.88%
4.70%-6.20%
$1,650,000
3,483,303
762,859
660,000
2,215,000
$2,110,000
3,008,363
462,914
980,000
1,410,000
1.75%
5.31%
5.00%
1.55%-2.88%
2.375%-5.88%
5.00%
1.55%-2.88%
2.375%-5.88%
5.00%
86,655
291,000
198,680
86,655
291,000
198,680
3.88%
2.04%-5.93%
2.04%-5.93%
785,059
883,243
3.53%
2.62%-5.33%
1.38%-5.69%
630,000
634,800
n/a
n/a
n/a
(b)
n/a
—
n/a
n/a
n/a
3.625%
4.70%
5.125%
(b)
1.93%
—
7.45%
5.13%
—
3.625%
4.70%
5.125%
(b)
1.96%
—
7.45%
5.13%
1.13%
550,000
500,000
450,000
79,638
695,000
181,329
128,488
50,671
—
550,000
500,000
450,000
95,011
255,000
181,253
148,716
97,414
250,000
(12,529)
14,331
13,399,484
(11,172)
14,367
12,596,244
899,375
457,095
$12,500,109
$13,607,242
$12,139,149
$12,439,785
Consists of pollution control revenue bonds and environmental revenue bonds, some of which are secured by
collateral first mortgage bonds.
131
E-5 Page 79 of 182
Entergy Corporation and Subsidiaries
Notes to Financial Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41
(b)
(c)
These notes do not have a stated interest rate, but have an implicit interest rate of 4.8%.
Pursuant to the Nuclear Waste Policy Act of 1982, Entergy’s nuclear owner/licensee subsidiaries have contracts
with the DOE for spent nuclear fuel disposal service. The contracts include a one-time fee for generation prior
to April 7, 1983. Entergy Arkansas is the only Entergy company that generated electric power with nuclear
fuel prior to that date and includes the one-time fee, plus accrued interest, in long-term debt.
See Note 10 to the financial statements for further discussion of the Waterford 3 and Grand Gulf lease
obligations.
The fair value excludes lease obligations of $128 million at Entergy Louisiana and $51 million at System
Energy, long-term DOE obligations of $181 million at Entergy Arkansas, and the note payable to NYPA of
$80 million at Entergy, and includes debt due within one year. Fair values are classified as Level 2 in the fair
value hierarchy discussed in Note 16 to the financial statements and are based on prices derived from inputs
such as benchmark yields and reported trades.
(d)
(e)
The annual long-term debt maturities (excluding lease obligations and long-term DOE obligations) for debt
outstanding as of December 31, 2014, for the next five years are as follows:
2015
2016
2017
2018
2019
Amount
(In Thousands)
$310,566
$765,821
$266,801
$1,336,396
$1,492,107
In November 2000, Entergy’s non-utility nuclear business purchased the FitzPatrick and Indian Point 3 power
plants in a seller-financed transaction. Entergy issued notes to NYPA with seven annual installments of approximately
$108 million commencing one year from the date of the closing, and eight annual installments of $20 million
commencing eight years from the date of the closing. These notes do not have a stated interest rate, but have an implicit
interest rate of 4.8%. In accordance with the purchase agreement with NYPA, the purchase of Indian Point 2 in 2001
resulted in Entergy becoming liable to NYPA for an additional $10 million per year for 10 years, beginning in September
2003. This liability was recorded upon the purchase of Indian Point 2 in September 2001. In July 2003 a payment of
$102 million was made prior to maturity on the note payable to NYPA. Under a provision in a letter of credit supporting
these notes, if certain of the Utility operating companies or System Energy were to default on other indebtedness,
Entergy could be required to post collateral to support the letter of credit.
Entergy Gulf States Louisiana, Entergy Louisiana, Entergy Mississippi, Entergy Texas, and System Energy
have obtained long-term financing authorizations from the FERC that extend through October 2015. Entergy Arkansas
has obtained long-term financing authorization from the APSC that extends through December 2015. Entergy New
Orleans has obtained long-term financing authorization from the City Council that extends through July 2016.
Capital Funds Agreement
Pursuant to an agreement with certain creditors, Entergy Corporation has agreed to supply System Energy with
sufficient capital to:
•
•
•
•
maintain System Energy’s equity capital at a minimum of 35% of its total capitalization (excluding shortterm debt);
permit the continued commercial operation of Grand Gulf;
pay in full all System Energy indebtedness for borrowed money when due; and
enable System Energy to make payments on specific System Energy debt, under supplements to the
agreement assigning System Energy’s rights in the agreement as security for the specific debt.
132
E-5 Page 80 of 182
Entergy Corporation and Subsidiaries
Notes to Financial
Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc.
41
Long-term debt for the Registrant Subsidiaries as of December 31, 2014 and 2013 consisted of:
2014
2013
(In Thousands)
Entergy Arkansas
Mortgage Bonds:
5.0% Series due July 2018
3.75% Series due February 2021
3.05% Series due June 2023
3.7% Series due June 2024
5.66% Series due February 2025
5.9% Series due June 2033
6.38% Series due November 2034
5.75% Series due November 2040
4.95% Series due December 2044
4.9% Series due December 2052
4.75% Series due June 2063
Total mortgage bonds
Governmental Bonds (a):
1.55% Series due 2017, Jefferson County (d)
2.375% Series due 2021, Independence County (d)
Total governmental bonds
Variable Interest Entity Notes Payable (Note 4):
5.69% Series I due July 2014
3.23% Series J due July 2016
2.62% Series K due December 2017
3.65% Series L due July 2021
Total variable interest entity notes payable
Securitization Bonds:
2.30% Series Senior Secured due August 2021
Total securitization bonds
Other:
Long-term DOE Obligation (b)
Term Loan due January 2015, weighted avg rate 1.13%
Unamortized Premium and Discount – Net
Other
Total Long-Term Debt
Less Amount Due Within One Year
Long-Term Debt Excluding Amount Due Within One Year
Fair Value of Long-Term Debt (c)
133
$—
350,000
250,000
375,000
175,000
100,000
60,000
225,000
250,000
200,000
125,000
2,110,000
$115,000
350,000
250,000
—
175,000
100,000
60,000
225,000
—
200,000
125,000
1,600,000
54,700
45,000
99,700
54,700
45,000
99,700
—
55,000
60,000
90,000
205,000
70,000
55,000
60,000
—
185,000
76,185
76,185
88,986
88,986
181,329
—
(2,960)
2,089
2,671,343
—
$2,671,343
$2,517,633
181,253
250,000
(1,242)
2,105
2,405,802
70,000
$2,335,802
$2,142,527
E-5 Page 81 of 182
Entergy Corporation and Subsidiaries
Notes to Financial Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41
2014
2013
(In Thousands)
Entergy Gulf States Louisiana
Mortgage Bonds:
6.0% Series due May 2018
3.95% Series due October 2020
5.59% Series due October 2024
3.78% Series due April 2025
6.2% Series due July 2033
6.18% Series due March 2035
Total mortgage bonds
Governmental Bonds (a):
2.875% Series due 2015, Louisiana Public Facilities Authority (d)
5.0% Series due 2028, Louisiana Public Facilities Authority (d)
Total governmental bonds
Variable Interest Entity Notes Payable (Note 4):
3.25% Series Q due July 2017
3.38% Series R due August 2020
Credit Facility due June 2016, weighted avg rate 1.38%
Total variable interest entity notes payable
Other:
Unamortized Premium and Discount – Net
Other
Total Long-Term Debt
Less Amount Due Within One Year
Long-Term Debt Excluding Amount Due Within One Year
Fair Value of Long-Term Debt (c)
134
$375,000
250,000
300,000
110,000
240,000
85,000
1,360,000
$375,000
250,000
300,000
—
240,000
85,000
1,250,000
31,955
83,680
115,635
31,955
83,680
115,635
75,000
70,000
—
145,000
75,000
70,000
14,800
159,800
(1,422)
3,604
1,622,817
31,955
$1,590,862
$1,743,143
(1,574)
3,604
1,527,465
—
$1,527,465
$1,631,308
E-5 Page 82 of 182
Entergy Corporation and Subsidiaries
Notes to Financial
Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc.
41
2014
2013
(In Thousands)
Entergy Louisiana
Mortgage Bonds:
1.875% Series due December 2014
6.50% Series due September 2018
4.8% Series due May 2021
3.3% Series due December 2022
4.05% Series due September 2023
5.40% Series due November 2024
3.78% Series due April 2025
4.44% Series due January 2026
6.4% Series due October 2034
6.3% Series due September 2035
6.0% Series due March 2040
5.875% Series due June 2041
5.0% Series due July 2044
4.95% Series due January 2045
5.25% Series due July 2052
4.7% Series due June 2063
Total mortgage bonds
Governmental Bonds (a):
5.0% Series due 2030, Louisiana Public Facilities Authority (d)
Total governmental bonds
Variable Interest Entity Notes Payable (Note 4):
5.69% Series E due July 2014
3.30% Series F due March 2016
3.25% Series G due July 2017
3.92% Series H due February 2021
Total variable interest entity notes payable
Securitization Bonds:
2.04% Series Senior Secured due June 2021
Total securitization bonds
Other:
Waterford 3 Lease Obligation 7.45% (Note 10)
Unamortized Premium and Discount - Net
Other
Total Long-Term Debt
Less Amount Due Within One Year
Long-Term Debt Excluding Amount Due Within One Year
Fair Value of Long-Term Debt (c)
135
$—
300,000
200,000
200,000
325,000
400,000
190,000
250,000
—
—
150,000
150,000
170,000
250,000
200,000
100,000
2,885,000
$250,000
300,000
200,000
200,000
325,000
400,000
—
250,000
70,000
100,000
150,000
150,000
—
—
200,000
100,000
2,695,000
115,000
115,000
115,000
115,000
—
20,000
25,000
40,000
85,000
50,000
20,000
25,000
—
95,000
143,064
143,064
164,993
164,993
128,488
(3,719)
3,746
3,356,579
19,525
$3,337,054
$3,447,404
148,716
(2,962)
3,769
3,219,516
320,231
$2,899,285
$3,148,877
E-5 Page 83 of 182
Entergy Corporation and Subsidiaries
Notes to Financial Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41
2014
2013
(In Thousands)
Entergy Mississippi
Mortgage Bonds:
3.25% Series due June 2016
4.95% Series due June 2018
6.64% Series due July 2019
3.1% Series due July 2023
3.75% Series due July 2024
6.0% Series due November 2032
6.25% Series due April 2034
6.20% Series due April 2040
6.0% Series due May 2051
Total mortgage bonds
Governmental Bonds (a):
4.90% Series due 2022, Independence County (d)
Total governmental bonds
Other:
Unamortized Premium and Discount – Net
Total Long-Term Debt
Less Amount Due Within One Year
Long-Term Debt Excluding Amount Due Within One Year
Fair Value of Long-Term Debt (c)
$125,000
—
150,000
250,000
100,000
75,000
100,000
80,000
150,000
1,030,000
$125,000
95,000
150,000
250,000
—
75,000
100,000
80,000
150,000
1,025,000
30,000
30,000
30,000
30,000
(1,162)
1,058,838
—
$1,058,838
$1,102,741
(1,330)
1,053,670
—
$1,053,670
$1,067,006
2014
2013
(In Thousands)
Entergy New Orleans
Mortgage Bonds:
5.10% Series due December 2020
3.9% Series due July 2023
5.6% Series due September 2024
5.65% Series due September 2029
5.0% Series due December 2052
Total mortgage bonds
Other:
Unamortized Premium and Discount – Net
Total Long-Term Debt
Less Amount Due Within One Year
Long-Term Debt Excluding Amount Due Within One Year
Fair Value of Long-Term Debt (c)
136
$25,000
100,000
33,303
37,859
30,000
226,162
$25,000
100,000
33,363
37,914
30,000
226,277
(296)
225,866
—
$225,866
$226,349
(333)
225,944
—
$225,944
$217,692
E-5 Page 84 of 182
Entergy Corporation and Subsidiaries
Notes to Financial
Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc.
41
2014
2013
(In Thousands)
Entergy Texas
Mortgage Bonds:
3.60% Series due June 2015
7.125% Series due February 2019
4.1% Series due September 2021
7.875% Series due June 2039
5.625% Series due June 2064
Total mortgage bonds
Securitization Bonds:
2.12% Series Senior Secured, Series A due February 2016
5.79% Series Senior Secured, Series A due October 2018
3.65% Series Senior Secured, Series A due August 2019
5.93% Series Senior Secured, Series A due June 2022
4.38% Series Senior Secured, Series A due November 2023
Total securitization bonds
Other:
Unamortized Premium and Discount - Net
Other
Total Long-Term Debt
Less Amount Due Within One Year
Long-Term Debt Excluding Amount Due Within One Year
Fair Value of Long-Term Debt (c)
137
$200,000
500,000
75,000
—
135,000
910,000
$200,000
500,000
75,000
150,000
—
925,000
13,816
74,194
144,800
114,400
218,600
565,810
54,047
97,414
144,800
114,400
218,600
629,261
(1,769)
4,890
1,478,931
200,000
$1,278,931
$1,629,124
(2,211)
4,889
1,556,939
—
$1,556,939
$1,726,623
E-5 Page 85 of 182
Entergy Corporation and Subsidiaries
Notes to Financial Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41
2014
2013
(In Thousands)
System Energy
Mortgage Bonds:
4.1% Series due April 2023
Total mortgage bonds
Governmental Bonds (a):
5.875% Series due 2022, Mississippi Business Finance Corp.
Total governmental bonds
Variable Interest Entity Notes Payable (Note 4):
5.33% Series G due April 2015
4.02% Series H due February 2017
3.78% Series I due October 2018
Total variable interest entity notes payable
Other:
Grand Gulf Lease Obligation 5.13% (Note 10)
Unamortized Premium and Discount – Net
Other
Total Long-Term Debt
Less Amount Due Within One Year
Long-Term Debt Excluding Amount Due Within One Year
Fair Value of Long-Term Debt (c)
(a)
(b)
(c)
(d)
$250,000
250,000
$250,000
250,000
216,000
216,000
216,000
216,000
60,000
50,000
85,000
195,000
60,000
50,000
85,000
195,000
50,671
(867)
2
710,806
76,310
$634,496
$677,475
97,414
(981)
3
757,436
48,653
$708,783
$664,890
Consists of pollution control revenue bonds and environmental revenue bonds.
Pursuant to the Nuclear Waste Policy Act of 1982, Entergy’s nuclear owner/licensee subsidiaries have contracts
with the DOE for spent nuclear fuel disposal service. The contracts include a one-time fee for generation prior
to April 7, 1983. Entergy Arkansas is the only Entergy company that generated electric power with nuclear
fuel prior to that date and includes the one-time fee, plus accrued interest, in long-term debt.
The fair value excludes lease obligations of $128 million at Entergy Louisiana and $51 million at System
Energy and long-term DOE obligations of $181 million at Entergy Arkansas, and includes debt due within one
year. Fair values are classified as Level 2 in the fair value hierarchy discussed in Note 16 to the financial
statements and are based on prices derived from inputs such as benchmark yields and reported trades.
The bonds are secured by a series of collateral first mortgage bonds.
The annual long-term debt maturities (excluding lease obligations and long-term DOE obligations) for debt
outstanding as of December 31, 2014, for the next five years are as follows:
2015
2016
2017
2018
2019
Entergy
Arkansas
$—
$55,000
$114,700
$—
$—
Entergy
Gulf States
Louisiana
$31,955
$—
$75,000
$375,000
$—
Entergy
Louisiana
$—
$20,000
$25,000
$300,000
$—
Entergy
Mississippi
$—
$125,000
$—
$—
$150,000
138
Entergy
New Orleans
$—
$—
$—
$—
$—
Entergy
Texas
$200,000
$13,816
$—
$74,194
$644,800
System
Energy
$60,000
$—
$50,000
$85,000
$—
E-5 Page 86 of 182
Entergy Corporation and Subsidiaries
Notes to Financial
Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc.
41
Entergy Arkansas Securitization Bonds
In June 2010 the APSC issued a financing order authorizing the issuance of bonds to recover Entergy Arkansas’s
January 2009 ice storm damage restoration costs, including carrying costs of $11.5 million and $4.6 million of upfront financing costs. In August 2010, Entergy Arkansas Restoration Funding, LLC, a company wholly-owned and
consolidated by Entergy Arkansas, issued $124.1 million of storm cost recovery bonds. The bonds have a coupon of
2.30% and an expected maturity date of August 2021. Although the principal amount is not due until the date given
above, Entergy Arkansas Restoration Funding expects to make principal payments on the bonds over the next five
years in the amount of $13.2 million for 2015, $13.4 million for 2016, $13.8 million for 2017, $14.1 million for 2018,
and $14.4 million for 2019. With the proceeds, Entergy Arkansas Restoration Funding purchased from Entergy
Arkansas the storm recovery property, which is the right to recover from customers through a storm recovery charge
amounts sufficient to service the securitization bonds. The storm recovery property is reflected as a regulatory asset
on the consolidated Entergy Arkansas balance sheet. The creditors of Entergy Arkansas do not have recourse to the
assets or revenues of Entergy Arkansas Restoration Funding, including the storm recovery property, and the creditors
of Entergy Arkansas Restoration Funding do not have recourse to the assets or revenues of Entergy Arkansas. Entergy
Arkansas has no payment obligations to Entergy Arkansas Restoration Funding except to remit storm recovery charge
collections.
Entergy Louisiana Securitization Bonds – Little Gypsy
In August 2011 the LPSC issued a financing order authorizing the issuance of bonds to recover Entergy
Louisiana’s investment recovery costs associated with the cancelled Little Gypsy repowering project. In September
2011, Entergy Louisiana Investment Recovery Funding I, L.L.C., a company wholly-owned and consolidated by
Entergy Louisiana, issued $207.2 million of senior secured investment recovery bonds. The bonds have an interest
rate of 2.04% and an expected maturity date of June 2021. Although the principal amount is not due until the date
given above, Entergy Louisiana Investment Recovery Funding expects to make principal payments on the bonds over
the next five years in the amounts of $20.5 million for 2015, $21.6 million for 2016, $21.7 million for 2017, $22.3
million for 2018, and $22.7 million for 2019. With the proceeds, Entergy Louisiana Investment Recovery Funding
purchased from Entergy Louisiana the investment recovery property, which is the right to recover from customers
through an investment recovery charge amounts sufficient to service the bonds. In accordance with the financing order,
Entergy Louisiana will apply the proceeds it received from the sale of the investment recovery property as a
reimbursement for previously-incurred investment recovery costs. The investment recovery property is reflected as a
regulatory asset on the consolidated Entergy Louisiana balance sheet. The creditors of Entergy Louisiana do not have
recourse to the assets or revenues of Entergy Louisiana Investment Recovery Funding, including the investment
recovery property, and the creditors of Entergy Louisiana Investment Recovery Funding do not have recourse to the
assets or revenues of Entergy Louisiana. Entergy Louisiana has no payment obligations to Entergy Louisiana
Investment Recovery Funding except to remit investment recovery charge collections.
139
E-5 Page 87 of 182
Entergy Corporation and Subsidiaries
Notes to Financial Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41
Entergy Texas Securitization Bonds - Hurricane Rita
In April 2007 the PUCT issued a financing order authorizing the issuance of securitization bonds to recover
$353 million of Entergy Texas’s Hurricane Rita reconstruction costs and up to $6 million of transaction costs, offset
by $32 million of related deferred income tax benefits. In June 2007, Entergy Gulf States Reconstruction Funding I,
LLC, a company that is now wholly-owned and consolidated by Entergy Texas, issued $329.5 million of senior secured
transition bonds (securitization bonds) as follows:
Amount
(In Thousands)
Senior Secured Transition Bonds, Series A:
Tranche A-1 (5.51%) due October 2013
Tranche A-2 (5.79%) due October 2018
Tranche A-3 (5.93%) due June 2022
Total senior secured transition bonds
$93,500
121,600
114,400
$329,500
Although the principal amount of each tranche is not due until the dates given above, Entergy Gulf States Reconstruction
Funding expects to make principal payments on the bonds over the next five years in the amounts of $24.6 million for
2015, $26 million for 2016, $27.6 million for 2017, $29.2 million for 2018, and $30.9 million for 2019. All of the
scheduled principal payments for 2015-2016 are for Tranche A-2, $23.6 million of the scheduled principal payments
for 2017 are for Tranche A-2 and $4 million of the scheduled principal payments for 2017 are for Tranche A-3. All of
the scheduled principal payments for 2018-2019 are for Tranche A-3.
With the proceeds, Entergy Gulf States Reconstruction Funding purchased from Entergy Texas the transition
property, which is the right to recover from customers through a transition charge amounts sufficient to service the
securitization bonds. The transition property is reflected as a regulatory asset on the consolidated Entergy Texas balance
sheet. The creditors of Entergy Texas do not have recourse to the assets or revenues of Entergy Gulf States
Reconstruction Funding, including the transition property, and the creditors of Entergy Gulf States Reconstruction
Funding do not have recourse to the assets or revenues of Entergy Texas. Entergy Texas has no payment obligations
to Entergy Gulf States Reconstruction Funding except to remit transition charge collections.
Entergy Texas Securitization Bonds - Hurricane Ike and Hurricane Gustav
In September 2009 the PUCT authorized the issuance of securitization bonds to recover $566.4 million of
Entergy Texas’s Hurricane Ike and Hurricane Gustav restoration costs, plus carrying costs and transaction costs, offset
by insurance proceeds. In November 2009, Entergy Texas Restoration Funding, LLC (Entergy Texas Restoration
Funding), a company wholly-owned and consolidated by Entergy Texas, issued $545.9 million of senior secured
transition bonds (securitization bonds), as follows:
Amount
(In Thousands)
Senior Secured Transition Bonds
Tranche A-1 (2.12%) due February 2016
Tranche A-2 (3.65%) due August 2019
Tranche A-3 (4.38%) due November 2023
Total senior secured transition bonds
$182,500
144,800
218,600
$545,900
Although the principal amount of each tranche is not due until the dates given above, Entergy Texas Restoration Funding
expects to make principal payments on the bonds over the next five years in the amount of $41.2 million for 2015,
$42.6 million for 2016, $44.1 million for 2017, $45.8 million for 2018, and $47.6 million for 2019. A total of $13.8
million of the scheduled principal payments for 2015 are for Tranche A-1 and $27.4 million are for Tranche A-2. All
140
E-5 Page 88 of 182
Entergy Corporation and Subsidiaries
Notes to Financial
Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc.
41
of the scheduled principal payments for 2016-2017 are for Tranche A-2, $30.8 million of the scheduled principal
payments for 2018 are for Tranche A-2 and $15 million are for Tranche A-3. All of the scheduled principle payments
for 2019 are for Tranche A-3.
With the proceeds, Entergy Texas Restoration Funding purchased from Entergy Texas the transition property,
which is the right to recover from customers through a transition charge amounts sufficient to service the securitization
bonds. The transition property is reflected as a regulatory asset on the consolidated Entergy Texas balance sheet. The
creditors of Entergy Texas do not have recourse to the assets or revenues of Entergy Texas Restoration Funding,
including the transition property, and the creditors of Entergy Texas Restoration Funding do not have recourse to the
assets or revenues of Entergy Texas. Entergy Texas has no payment obligations to Entergy Texas Restoration Funding
except to remit transition charge collections.
NOTE 6. PREFERRED EQUITY (Entergy Corporation, Entergy Arkansas, Entergy Gulf States Louisiana,
Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans)
The number of shares and units authorized and outstanding and dollar value of preferred stock, preferred
membership interests, and non-controlling interest for Entergy Corporation subsidiaries as of December 31, 2014 and
2013 are presented below. All series of the Utility preferred stock are redeemable at the option of the related company.
Shares/Units
Authorized
2014
2013
Entergy Corporation
Utility:
Preferred Stock or Preferred
Membership Interests without
sinking fund:
Entergy Arkansas, 4.32%-6.45%
Series
Entergy Gulf States Louisiana,
Series A 8.25%
Entergy Louisiana, 6.95% Series
(a)
Entergy Mississippi, 4.36%-6.25%
Series
Entergy New Orleans,
4.36%-5.56% Series
Total Utility Preferred Stock or
Preferred Membership Interests
without sinking fund
Entergy Wholesale Commodities:
Preferred Stock without sinking
fund:
Entergy Finance Holding, Inc.
8.75% (b)
Total Subsidiaries’ Preferred Stock
without sinking fund
(a)
(b)
Shares/Units
Outstanding
2014
2013
2014
2013
(Dollars in Thousands)
3,413,500
3,413,500
3,413,500
3,413,500
$116,350
$116,350
100,000
1,000,000
100,000
1,000,000
100,000
840,000
100,000
840,000
10,000
84,000
10,000
84,000
1,403,807
1,403,807
1,403,807
1,403,807
50,381
50,381
197,798
197,798
197,798
197,798
19,780
19,780
6,115,105
6,115,105
5,955,105
5,955,105
280,511
280,511
250,000
250,000
250,000
250,000
24,249
24,249
6,365,105
6,365,105
6,205,105
6,205,105
$304,760
$304,760
In 2007, Entergy Louisiana Holdings, an Entergy subsidiary, purchased 160,000 of these shares from the
holders.
Dollar amount outstanding is net of $751 thousand of preferred stock issuance costs.
141
E-5 Page 89 of 182
Entergy Corporation and Subsidiaries
Notes to Financial Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41
In December 2013, Entergy Finance Holding, Inc. issued 250,000 shares of $100 par value 8.75% Series
Preferred Stock, all of which are outstanding as of December 31, 2014. The dividends are cumulative and payable
quarterly. The preferred stock is redeemable on or after December 16, 2023, at Entergy Finance Holding, Inc.’s option,
at the fixed redemption price of $100 per share.
The number of shares and units authorized and outstanding and dollar value of preferred stock and membership
interests for Entergy Arkansas, Entergy Gulf States Louisiana, Entergy Louisiana, Entergy Mississippi, and Entergy
New Orleans as of December 31, 2014 and 2013 are presented below. All series of the Utility operating companies’
preferred stock and membership interests are redeemable at the respective company’s option at the call prices
presented. Dividends and distributions paid on all of Entergy’s preferred stock and membership interests series are
eligible for the dividends received deduction. The dividends received deduction is limited by Internal Revenue Code
section 244 for the following preferred stock series: Entergy Arkansas 4.72%, Entergy Mississippi 4.56%, and Entergy
New Orleans 4.75%.
Shares
Authorized
and Outstanding
2014
2013
Entergy Arkansas Preferred Stock
Without sinking fund:
Cumulative, $100 par value:
4.32% Series
4.72% Series
4.56% Series
4.56% 1965 Series
6.08% Series
Cumulative, $25 par value:
6.45% Series
Total without sinking fund
2013
(Dollars in Thousands)
70,000
93,500
75,000
75,000
100,000
70,000
93,500
75,000
75,000
100,000
$7,000
9,350
7,500
7,500
10,000
$7,000
9,350
7,500
7,500
10,000
$103.65
$107.00
$102.83
$102.50
$102.83
3,000,000
3,413,500
3,000,000
3,413,500
75,000
$116,350
75,000
$116,350
$25
Units
Authorized
and Outstanding
2014
2013
Entergy Gulf States Louisiana
Preferred Membership Interests
Without sinking fund:
Cumulative, $100 liquidation value:
8.25% Series (a)
Total without sinking fund
2014
Call Price
per
Share as of
December 31,
2014
2014
2013
Call Price
per
Unit as of
December 31,
2014
(Dollars in Thousands)
100,000
100,000
100,000
100,000
142
$10,000
$10,000
$10,000
$10,000
$—
E-5 Page 90 of 182
Entergy Corporation and Subsidiaries
Notes to Financial
Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc.
41
Units
Authorized
and Outstanding
2014
2013
Entergy Louisiana Preferred
Membership Interests
Without sinking fund:
Cumulative, $100 liquidation value:
6.95% Series
Total without sinking fund
1,000,000
1,000,000
1,000,000
1,000,000
(a)
$100,000
$100,000
2014
$100,000
$100,000
2013
$100
Call Price
per
Share as of
December 31,
2014
(Dollars in Thousands)
59,920
43,887
100,000
59,920
43,887
100,000
$5,992
4,389
10,000
$5,992
4,389
10,000
$103.86
$107.00
$102.88
1,200,000
1,403,807
1,200,000
1,403,807
30,000
$50,381
30,000
$50,381
$25
Shares
Authorized
and Outstanding
2014
2013
Entergy New Orleans Preferred
Stock
Without sinking fund:
Cumulative, $100 par value:
4.36% Series
4.75% Series
5.56% Series
Total without sinking fund
2013
(Dollars in Thousands)
Shares
Authorized
and Outstanding
2014
2013
Entergy Mississippi Preferred Stock
Without sinking fund:
Cumulative, $100 par value:
4.36% Series
4.56% Series
4.92% Series
Cumulative, $25 par value
6.25% Series
Total without sinking fund
2014
Call Price
per
Unit as of
December 31,
2014
2014
2013
Call Price
per
Share as of
December 31,
2014
(Dollars in Thousands)
60,000
77,798
60,000
197,798
60,000
77,798
60,000
197,798
$6,000
7,780
6,000
$19,780
$6,000
7,780
6,000
$19,780
$104.58
$105.00
$102.59
Series is callable at par on and after December 15, 2015.
143
E-5 Page 91 of 182
Entergy Corporation and Subsidiaries
Notes to Financial Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41
NOTE 7. COMMON EQUITY (Entergy Corporation, Entergy Arkansas, Entergy Gulf States Louisiana,
Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)
Common Stock
Common stock and treasury stock shares activity for Entergy for 2014, 2013, and 2012 is as follows:
2014
Common
Shares
Treasury
Issued
Shares
Beginning Balance,
January 1
Repurchases
Issuances:
Employee StockBased Compensation
Plans
Directors’ Plan
Ending Balance,
December 31
254,752,788
—
—
—
254,752,788
76,381,936
2,154,490
2013
Common
Shares
Treasury
Issued
Shares
254,752,788
—
(3,019,475)
(4,872)
75,512,079
—
—
254,752,788
76,945,239
—
(557,734)
(5,569)
76,381,936
2012
Common
Shares
Treasury
Issued
Shares
254,752,788
—
—
—
254,752,788
78,396,988
—
(1,446,305)
(5,444)
76,945,239
Entergy Corporation reissues treasury shares to meet the requirements of the Stock Plan for Outside Directors
(Directors’ Plan), two Equity Ownership Plans of Entergy Corporation and Subsidiaries, the Equity Awards Plan of
Entergy Corporation and Subsidiaries, and certain other stock benefit plans. The Directors’ Plan awards to nonemployee directors a portion of their compensation in the form of a fixed dollar value of shares of Entergy Corporation
common stock.
In October 2010 the Board granted authority for a $500 million share repurchase program. As of December 31,
2014, $350 million of authority remains under the $500 million share repurchase program.
Dividends declared per common share were $3.32 in 2014, 2013, and 2012.
Retained Earnings and Dividend Restrictions
Provisions within the articles of incorporation or pertinent indentures and various other agreements relating
to the long-term debt and preferred stock of certain of Entergy Corporation’s subsidiaries could restrict the payment
of cash dividends or other distributions on their common and preferred equity. As of December 31, 2014, under
provisions in their mortgage indentures, Entergy Arkansas and Entergy Mississippi had retained earnings unavailable
for distribution to Entergy Corporation of $394.9 million and $68.5 million, respectively. Entergy Corporation received
dividend payments from subsidiaries totaling $893 million in 2014, $702 million in 2013, and $439 million in 2012.
144
E-5 Page 92 of 182
Entergy Corporation and Subsidiaries
Notes to Financial
Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc.
41
Comprehensive Income
Accumulated other comprehensive income (loss) is included in the equity section of the balance sheets of
Entergy, Entergy Gulf States Louisiana, and Entergy Louisiana. The following table presents changes in accumulated
other comprehensive income (loss) for Entergy for the year ended December 31, 2014 by component:
Cash flow
hedges
net
unrealized
gain (loss)
Beginning balance, December 31,
2013
Other comprehensive income
(loss) before reclassifications
Amounts reclassified from
accumulated other comprehensive
income (loss)
Net other comprehensive income
(loss) for the period
Ending balance, December 31,
2014
Pension
and
Net
other
unrealized
Foreign
postretirement investment currency
liabilities
gains (loss) translation
(In Thousands)
$3,420
Total
Accumulated
Other
Comprehensive
Income (Loss)
($81,777)
($288,223)
$337,256
52,433
(278,361)
99,900
(751)
(126,779)
127,462
(3,205)
(10,461)
—
113,796
179,895
(281,566)
89,439
(751)
(12,983)
$98,118
($569,789)
$426,695
$2,669
($29,324)
($42,307)
The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the
year ended December 31, 2013 by component:
Cash flow
hedges
net
unrealized
gain (loss)
Beginning balance, December 31,
2012
Other comprehensive income
(loss) before reclassifications
Amounts reclassified from
accumulated other comprehensive
income (loss)
Net other comprehensive income
(loss) for the period
Ending balance, December 31,
2013
Pension
and
Net
other
unrealized
Foreign
postretirement investment currency
liabilities
gains (loss) translation
(In Thousands)
$79,905
($590,712)
$214,547
$3,177
(133,312)
260,567
143,936
243
(28,370)
41,922
(21,227)
—
(161,682)
302,489
122,709
243
($81,777)
($288,223)
$337,256
$3,420
145
Total
Accumulated
Other
Comprehensive
Income (Loss)
($293,083)
271,434
(7,675)
263,759
($29,324)
E-5 Page 93 of 182
Entergy Corporation and Subsidiaries
Notes to Financial Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41
The following table presents changes in accumulated other comprehensive income (loss) for Entergy Gulf
States Louisiana and Entergy Louisiana for the year ended December 31, 2014:
Pension and Other
Postretirement Liabilities
Entergy
Gulf States
Entergy
Louisiana
Louisiana
(In Thousands)
Beginning balance, December 31, 2013
Other comprehensive income (loss) before
reclassifications
Amounts reclassified from accumulated other
comprehensive income (loss)
Net other comprehensive income (loss) for the period
Ending balance, December 31, 2014
($28,202)
($9,635)
(25,677)
(15,078)
532
(25,145)
($53,347)
(1,163)
(16,241)
($25,876)
The following table presents changes in accumulated other comprehensive income (loss) for Entergy Gulf
States Louisiana and Entergy Louisiana for the year ended December 31, 2013:
Pension and Other
Postretirement Liabilities
Entergy
Gulf States
Entergy
Louisiana
Louisiana
(In Thousands)
Beginning balance, December 31, 2012
Other comprehensive income (loss) before
reclassifications
Amounts reclassified from accumulated other
comprehensive income (loss)
Net other comprehensive income (loss) for the period
Ending balance, December 31, 2013
146
($65,229)
($46,132)
33,233
33,869
3,794
37,027
($28,202)
2,628
36,497
($9,635)
E-5 Page 94 of 182
Entergy Corporation and Subsidiaries
Notes to Financial
Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc.
41
Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) for Entergy for the year
ended December 31, 2014 are as follows:
Amounts
reclassified
from
AOCI
(In Thousands)
Cash flow hedges net unrealized gain (loss)
Power contracts
Interest rate swaps
Total realized gain (loss) on cash flow hedges
($193,297) Competitive business operating revenues
(2,799) Miscellaneous - net
(196,096)
68,634 Income taxes
Total realized gain (loss) on cash flow hedges (net
of tax)
($127,462)
Pension and other postretirement liabilities
Amortization of prior-service costs
Amortization of loss
Settlement loss
Total amortization
$20,294
(35,836)
(3,643)
(19,185)
22,390
$3,205
Total amortization (net of tax)
Net unrealized investment gain (loss)
Realized gain (loss)
(a)
(a)
(a)
Income taxes
$20,511 Interest and investment income
(10,050) Income taxes
$10,461
Total realized investment gain (loss) (net of tax)
Total reclassifications for the period (net of tax)
(a)
Income Statement Location
($113,796)
These accumulated other comprehensive income (loss) components are included in the computation of net
periodic pension cost. See Note 11 to the financial statements for additional details.
147
E-5 Page 95 of 182
Entergy Corporation and Subsidiaries
Notes to Financial Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41
Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) for Entergy for the year
ended December 31, 2013 are as follows:
Amounts
reclassified
from
AOCI
(In Thousands)
Cash flow hedges net unrealized gain (loss)
Power contracts
Interest rate swaps
Total realized gain (loss) on cash flow hedges
$47,019 Competitive business operating revenues
(1,565) Miscellaneous - net
45,454
(17,084) Income taxes
Total realized gain (loss) on cash flow hedges (net
of tax)
$28,370
Pension and other postretirement liabilities
Amortization of prior-service costs
Acceleration of prior-service cost due to
curtailment
Amortization of loss
Settlement loss
Total amortization
Total amortization (net of tax)
Net unrealized investment gain (loss)
Realized gain (loss)
$10,556
(a)
315
(68,130)
(11,612)
(68,871)
26,949
($41,922)
(a)
(a)
(a)
Income taxes
$41,622 Interest and investment income
(20,395) Income taxes
$21,227
Total realized investment gain (loss) (net of tax)
Total reclassifications for the period (net of tax)
(a)
Income Statement Location
$7,675
These accumulated other comprehensive income (loss) components are included in the computation of net
periodic pension cost. See Note 11 to the financial statements for additional details.
148
E-5 Page 96 of 182
Entergy Corporation and Subsidiaries
Notes to Financial
Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc.
41
Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) for Entergy Gulf States
Louisiana and Entergy Louisiana for the year ended December 31, 2014 are as follows:
Amounts reclassified
from AOCI
Entergy
Gulf States
Entergy
Louisiana
Louisiana
(In Thousands)
Pension and other postretirement liabilities
Amortization of prior-service costs
Amortization of loss
Total amortization
$2,237
(3,126)
(889)
357
(532)
Total amortization (net of tax)
Total reclassifications for the period (net of tax)
(a)
($532)
Income Statement
Location
$3,377 (a)
(1,511) (a)
1,866
Income tax expense
(703) (benefit)
1,163
$1,163
These accumulated other comprehensive income (loss) components are included in the computation of net
periodic pension cost. See Note 11 to the financial statements for additional details.
Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) for Entergy Gulf States
Louisiana and Entergy Louisiana for the year ended December 31, 2013 are as follows:
Amounts reclassified
from AOCI
Entergy
Gulf States
Entergy
Louisiana
Louisiana
(In Thousands)
Pension and other postretirement liabilities
Amortization of prior-service costs
Acceleration of prior-service cost due to
curtailment
Amortization of loss
Total amortization
$941
91
(7,644)
(6,612)
2,818
(3,794)
Total amortization (net of tax)
Total reclassifications for the period (net of tax)
(a)
($3,794)
$508
Income Statement
Location
(a)
41 (a)
(5,050) (a)
(4,501)
1,873 Income taxes
(2,628)
($2,628)
These accumulated other comprehensive income (loss) components are included in the computation of net
periodic pension cost. See Note 11 to the financial statements for additional details.
149
E-5 Page 97 of 182
Entergy Corporation and Subsidiaries
Notes to Financial Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41
NOTE 8. COMMITMENTS AND CONTINGENCIES (Entergy Corporation, Entergy Arkansas, Entergy
Gulf States Louisiana, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and
System Energy)
Entergy and the Registrant Subsidiaries are involved in a number of legal, regulatory, and tax proceedings
before various courts, regulatory commissions, and governmental agencies in the ordinary course of business. While
management is unable to predict the outcome of such proceedings, management does not believe that the ultimate
resolution of these matters will have a material effect on Entergy’s results of operations, cash flows, or financial
condition. Entergy discusses regulatory proceedings in Note 2 to the financial statements and discusses tax proceedings
in Note 3 to the financial statements.
Vidalia Purchased Power Agreement
Entergy Louisiana has an agreement extending through the year 2031 to purchase energy generated by a
hydroelectric facility known as the Vidalia project. Entergy Louisiana made payments under the contract of
approximately $152.8 million in 2014, $181.1 million in 2013, and $125.0 million in 2012. If the maximum percentage
(94%) of the energy is made available to Entergy Louisiana, current production projections would require estimated
payments of approximately $148.5 million in 2015, and a total of $2.06 billion for the years 2016 through 2031. Entergy
Louisiana currently recovers the costs of the purchased energy through its fuel adjustment clause.
In an LPSC-approved settlement related to tax benefits from the tax treatment of the Vidalia contract, Entergy
Louisiana agreed to credit rates by $11 million each year for up to 10 years, beginning in October 2002. In addition,
in accordance with an LPSC settlement, Entergy Louisiana credited rates in August 2007 by $11.3 million (including
interest) as a result of a settlement with the IRS of the 2001 tax treatment of the Vidalia contract. In August 2011,
Entergy agreed to a settlement with the IRS regarding the mark-to-market income tax treatment of various wholesale
electric power purchase and sale contracts, including the Vidalia contract. The agreement with the IRS effectively
settled the tax treatment of such contracts which allowed Entergy Louisiana to propose a final settlement with the
LPSC regarding Entergy Louisiana’s obligation to customers related to the Vidalia contract. In October 2011 the LPSC
approved a final settlement under which Entergy Louisiana agreed to provide credits to the fuel adjustment clause
resulting from the IRS settlement to customers by crediting billings an additional $20.235 million per year for 15 years
beginning January 2012. Entergy Louisiana recorded a regulatory charge and a corresponding regulatory liability to
reflect this obligation. Entergy Louisiana’s use of the cash benefit of the proceeds is not reflected in rate base for
ratemaking purposes.
ANO Damage, Outage, and NRC Reviews
On March 31, 2013, during a scheduled refueling outage at ANO 1, a contractor-owned and operated heavylifting apparatus collapsed while moving the generator stator out of the turbine building. The collapse resulted in the
death of an ironworker and injuries to several other contract workers, caused ANO 2 to shut down, and damaged the
ANO turbine building. The turbine building serves both ANO 1 and 2 and is a non-radiological area of the plant. ANO
2 reconnected to the grid on April 28, 2013 and ANO 1 reconnected to the grid on August 7, 2013. The total cost of
assessment, restoration of off-site power, site restoration, debris removal, and replacement of damaged property and
equipment was approximately $95 million. In addition, Entergy Arkansas incurred replacement power costs for ANO
2 power during its outage and incurred incremental replacement power costs for ANO 1 power because the outage
extended beyond the originally-planned duration of the refueling outage. In February 2014 the APSC approved Entergy
Arkansas’s request to exclude from the calculation of its revised energy cost rate $65.9 million of deferred fuel and
purchased energy costs incurred in 2013 as a result of the ANO stator incident. The APSC authorized Entergy Arkansas
to retain the $65.9 million in its deferred fuel balance with recovery to be reviewed in a later period after more information
regarding various claims associated with the ANO stator incident is available.
Entergy Arkansas is pursuing its options for recovering damages that resulted from the stator drop, including
its insurance coverage and legal action. Entergy is a member of Nuclear Electric Insurance Limited (NEIL), a mutual
150
E-5 Page 98 of 182
Entergy Corporation and Subsidiaries
Notes to Financial
Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc.
41
insurance company that provides property damage coverage to the members’ nuclear generating plants, including ANO.
NEIL has notified Entergy that it believes that a $50 million course of construction sublimit applies to any loss associated
with the lifting apparatus failure and stator drop at ANO. Entergy has responded that it disagrees with NEIL’s position
and is evaluating its options for enforcing its rights under the policy. During 2014, Entergy Arkansas collected $50
million from NEIL. On July 12, 2013, Entergy Arkansas filed a complaint in the Circuit Court in Pope County, Arkansas
against the owner of the heavy-lifting apparatus that collapsed, an engineering firm, a contractor, and certain individuals
asserting claims of breach of contract, negligence, and gross negligence in connection with their responsibility for the
stator drop.
Shortly after the stator incident, the NRC deployed an augmented inspection team to review the plant’s response.
In July 2013 a second team of NRC inspectors visited ANO to evaluate certain items that were identified as requiring
follow-up inspection to determine whether performance deficiencies existed. In March 2014 the NRC issued an
inspection report on the follow-up inspection that discussed two preliminary findings, one that was preliminarily
determined to be “red with high safety significance” for Unit 1 and one that was preliminarily determined to be “yellow
with substantial safety significance” for Unit 2, with the NRC indicating further that these preliminary findings may
warrant additional regulatory oversight. This report also noted that one additional item related to flood barrier
effectiveness was still under review.
In May 2014 the NRC met with Entergy during a regulatory conference to discuss the preliminary red and
yellow findings and Entergy’s response to the findings. During the regulatory conference, Entergy presented
information on the facts and assumptions the NRC used to assess the potential findings. The NRC used the information
provided by Entergy at the regulatory conference to finalize its decision regarding the inspection team’s findings. In
a letter dated June 23, 2014, the NRC classified both findings as “yellow with substantial safety significance.” In an
assessment follow-up letter for ANO dated July 29, 2014, the NRC stated that given the two yellow findings, it
determined that the performance at ANO is in the “degraded cornerstone column,” or column 3, of the NRC’s reactor
oversight process action matrix beginning the first quarter 2014. Corrective actions in response to the NRC’s findings
have been taken and remain ongoing at ANO. The NRC plans to conduct supplemental inspection activity to review
the actions taken to address the yellow findings. Entergy will continue to interact with the NRC to address the NRC’s
findings.
In September 2014 the NRC issued an inspection report on the flood barrier effectiveness issue that was still
under review at the time of the March 2014 inspection report. While Entergy believes that the flood barrier issues that
led to the finding have been addressed at ANO, NRC processes still required that the NRC assess the safety significance
of the deficiencies. In its September 2014 inspection report, the NRC discussed a preliminary finding of “yellow with
substantial safety significance” for the Unit 1 and Unit 2 auxiliary and emergency diesel fuel storage buildings. The
NRC indicated that these preliminary findings may warrant additional regulatory oversight. Entergy requested a public
regulatory conference regarding the inspection, and the conference was held on October 28, 2014. During the regulatory
conference, Entergy presented information related to the facts and assumptions used by the NRC in arriving at its
preliminary finding of “yellow with substantial safety significance.” In January 2015 the NRC issued its final risk
significance determination for the flood barrier violation originally cited in the September 2014 report. The NRC’s
final risk significance determination was classified as “yellow with substantial safety significance.”
The NRC’s January 2015 letter did not advise ANO of the additional level of oversight that will result from
the yellow finding related to the flood barrier issue, and it stated that the NRC would inform ANO of this decision by
separate correspondence. The yellow finding may result in ANO being placed into the “multiple/repetitive degraded
cornerstone column” of the NRC’s reactor oversight process action matrix. Placement into this column would require
significant additional NRC inspection activities at the ANO site, including a review of the site’s root cause evaluation
associated with the flood barrier and stator issues, an assessment of the effectiveness of the site’s corrective action
program, an additional design basis inspection, a safety culture assessment, and possibly other inspection activities
consistent with the NRC’s Inspection Procedure. The additional NRC inspection activities at the site are expected to
increase ANO’s operating costs.
151
E-5 Page 99 of 182
Entergy Corporation and Subsidiaries
Notes to Financial Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41
Baxter Wilson Plant Event
On September 11, 2013, Entergy Mississippi’s Baxter Wilson (Unit 1) power plant experienced a significant
unplanned outage event. Entergy Mississippi completed the repairs to the unit in December 2014. As of December
31, 2014, Entergy Mississippi incurred $22.3 million of capital spending and $26.6 million of operation and maintenance
expenses to return the unit to service. The damage was covered by Entergy Mississippi’s property insurance policy,
subject to a $20 million deductible. As of December 31, 2014, Entergy Mississippi recorded an insurance receivable
of $28.2 million for the amount expected to be received from its insurance policy, allocating $12.9 million of the
expected insurance proceeds to capital spending and $15.3 million to operation and maintenance expenses. In June
2014, Entergy Mississippi filed a rate case with the MPSC, which includes recovery of the costs associated with Baxter
Wilson (Unit 1) repair activities, net of applicable insurance proceeds. In December 2014 the MPSC issued an order
that provided for a deferral of $6 million in other operation and maintenance expenses associated with the Baxter
Wilson outage and that the regulatory asset should accrue carrying costs, with amortization of the regulatory asset to
occur over two years beginning in February 2015, and provided that the capital costs will be reflected in rate base.
The final accounting of costs to return the unit to service and insurance proceeds will be addressed in Entergy
Mississippi’s next formula rate plan filing.
Nuclear Insurance
Third Party Liability Insurance
The Price-Anderson Act requires that reactor licensees purchase insurance and participate in a secondary
insurance pool that provides insurance coverage for the public in the event of a nuclear power plant accident. The
costs of this insurance are borne by the nuclear power industry. Congress amended and renewed the Price-Anderson
Act in 2005 for a term through 2025. The Price-Anderson Act requires nuclear power plants to show evidence of
financial protection in the event of a nuclear accident. This protection must consist of two layers of coverage:
1. The primary level is private insurance underwritten by American Nuclear Insurers (ANI) and provides public
liability insurance coverage of $375 million. If this amount is not sufficient to cover claims arising from an
accident, the second level, Secondary Financial Protection, applies.
2. Within the Secondary Financial Protection level, each nuclear reactor has a contingent obligation to pay a
retrospective premium, equal to its proportionate share of the loss in excess of the primary level, regardless
of proximity to the incident or fault, up to a maximum of $127.3 million per reactor per incident (Entergy’s
maximum total contingent obligation per incident is $1.4 billion). This consists of a $121.3 million maximum
retrospective premium plus a five percent surcharge, which equates to $127.3 million, that may be payable, if
needed, at a rate that is currently set at $19.0 million per year per incident per nuclear power reactor.
3. In the event that one or more acts of terrorism cause a nuclear power plant accident, which results in thirdparty damages – off-site property and environmental damage, off-site bodily injury, and on-site third-party
bodily injury (i.e. contractors); the primary level provided by ANI combined with the Secondary Financial
Protection would provide $13.6 billion in coverage. The Terrorism Risk Insurance Reauthorization Act of
2007 created a government program that provides for up to $100 billion in coverage in excess of existing
coverage for a terrorist event. The Terrorism Risk Insurance Reauthorization Act of 2007 expired on December
31, 2014. However, The Terrorism Risk Insurance Reauthorization Act of 2015 was signed into law by the
President of the United States on January 12, 2015 thereby extending the Terrorism Risk Insurance Act for six
years until December 31, 2020.
Currently, 104 nuclear reactors are participating in the Secondary Financial Protection program. The product
of the maximum retrospective premium assessment to the nuclear power industry and the number of nuclear power
reactors provides over $13.2 billion in secondary layer insurance coverage to compensate the public in the event of a
nuclear power reactor accident. The Price-Anderson Act provides that all potential liability for a nuclear accident is
limited to the amounts of insurance coverage available under the primary and secondary layers.
152
E-5 Page 100 of 182
Entergy Corporation and Subsidiaries
Notes to Financial
Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc.
41
Entergy Arkansas has two licensed reactors and Entergy Gulf States Louisiana, Entergy Louisiana, and System
Energy each have one licensed reactor (10% of Grand Gulf is owned by a non-affiliated company (SMEPA) that would
share on a pro-rata basis in any retrospective premium assessment to System Energy under the Price-Anderson Act). The
Entergy Wholesale Commodities segment includes the ownership, operation, and decommissioning of nuclear power
reactors and the ownership of the shutdown Indian Point 1 reactor and Big Rock Point facility.
Property Insurance
Entergy’s nuclear owner/licensee subsidiaries are members of NEIL, a mutual insurance company that provides
property damage coverage, including decontamination and premature decommissioning expense, to the members’
nuclear generating plants. Effective April 1, 2014, Entergy was insured against such losses per the following structures:
Utility Plants (ANO 1 and 2, Grand Gulf, River Bend, and Waterford 3)
• Primary Layer (per plant) - $1.5 billion per occurrence
• Blanket Excess Layer (shared among the Utility plants) - $100 million per occurrence
• Total limit - $1.6 billion per occurrence
• Deductibles:
• $2.5 million per occurrence - Turbine/generator damage
• $2.5 million per occurrence - Other than turbine/generator damage
• $10 million per occurrence plus 10% of amount above $10 million - Damage from a windstorm, flood,
earthquake, or volcanic eruption
Note: ANO 1 and 2 share in the primary and blanket excess layers with common policies because the policies
are issued on a per site basis. Flood and earthquake coverage are excluded from the primary layer’s first $500 million
in coverage. Entergy currently purchases flood coverage at Waterford 3 and River Bend for the primary layer’s first
$500 million in coverage.
Entergy Wholesale Commodities Plants (FitzPatrick, Pilgrim, and Palisades)
• Primary Layer (per plant) - $1.115 billion per occurrence
• Total limit (per plant) - $1.115 billion per occurrence
• Deductibles:
• $2.5 million per occurrence - Turbine/generator damage
• $2.5 million per occurrence - Other than turbine/generator damage
• $10 million per occurrence plus 10% of amount above $10 million - Damage from a windstorm, flood,
earthquake, or volcanic eruption
Note: Flood and earthquake coverage are excluded from the primary layer’s first $500 million in coverage.
Entergy currently purchases flood and earthquake coverage at Palisades for the primary layer’s first $500 million in
coverage.
Entergy Wholesale Commodities Plant (Indian Point)
• Primary Layer (per plant) - $1.5 billion per occurrence
• Excess Layer - $100 million per occurrence
• Total limit - $1.6 billion per occurrence
• Deductibles:
• $2.5 million per occurrence - Turbine/generator damage
• $2.5 million per occurrence - Other than turbine/generator damage
• $10 million per occurrence plus 10% of amount above $10 million - Damage from a windstorm, flood,
earthquake, or volcanic eruption
Note: The Indian Point Units share in the primary and excess layers with common policies because the policies
are issued on a per site basis. Flood and earthquake coverage are excluded from the primary layer’s first $500 million
153
E-5 Page 101 of 182
Entergy Corporation and Subsidiaries
Notes to Financial Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41
in coverage. Entergy currently purchases flood coverage at Indian Point for the primary layer’s first $500 million in
coverage.
Entergy Wholesale Commodities Plant (Vermont Yankee)
• Primary Layer (per plant) - $1.06 billion per occurrence
• Total limit - $1.06 billion per occurrence
• Deductibles:
• $2.5 million per occurrence - Turbine/generator damage
• $2.5 million per occurrence - Other than turbine/generator damage
• $10 million per occurrence plus 10% of amount above $10 million - Damage from a windstorm, flood,
earthquake, or volcanic eruption
Note: Flood and earthquake coverage are excluded from the primary layer’s first $500 million in coverage.
Entergy currently purchases flood and earthquake coverage at Vermont Yankee for the primary layer’s first $500 million
in coverage.
Entergy Wholesale Commodities Plant (Big Rock Point)
• Primary Layer (per plant) - $500 million per occurrence
• Total limit - $500 million per occurrence
Note: Flood and earthquake coverage are excluded from the primary layer’s first $500 million in coverage.
Entergy currently purchases flood and earthquake coverage at Big Rock Point for the primary layer’s first $500 million
in coverage.
In addition, Waterford 3, Grand Gulf, and the Entergy Wholesale Commodities plants, with the exception of
Vermont Yankee, are also covered under NEIL’s Accidental Outage Coverage program. Due to the shutdown of the
Vermont Yankee Nuclear Power Plant in December 2014, and the required 12 week deductible waiting period for the
accidental outage coverage to take effect, accidental outage coverage was removed effective October 1, 2014. This
coverage provides certain fixed indemnities in the event of an unplanned outage that results from a covered NEIL
primary property damage loss, subject to a deductible period. The payout for damage resulting from non-nuclear events
is limited to a $327.6 million per occurrence sub-limit. The following summarizes this coverage effective October 1,
2014:
Waterford 3
• $2.95 million weekly indemnity
• $413 million maximum indemnity
• Deductible: 26 week deductible period
Grand Gulf
• $400,000 weekly indemnity (total for four policies)
• $56 million maximum indemnity (total for four policies)
• Deductible: 26 week deductible period
Indian Point 2, Indian Point 3, and Palisades
• $4.5 million weekly indemnity
• $490 million maximum indemnity
• Deductible: 12 week deductible period
FitzPatrick and Pilgrim
• $4 million weekly indemnity
• $490 million maximum indemnity
• Deductible: 12 week deductible period
154
E-5 Page 102 of 182
Entergy Corporation and Subsidiaries
Notes to Financial
Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc.
41
Under the property damage and accidental outage insurance programs, all NEIL insured plants could be subject
to assessments should losses exceed the accumulated funds available from NEIL. Effective April 1, 2014, the maximum
amounts of such possible assessments per occurrence were as follows:
Assessments
(In Millions)
Utility:
Entergy Arkansas
Entergy Gulf States Louisiana
Entergy Louisiana
Entergy Mississippi
Entergy New Orleans
Entergy Texas
System Energy
Entergy Wholesale Commodities
$32.2
$25.5
$26.1
$0.09
$0.09
N/A
$21.5
$—
Potential assessments for the Entergy Wholesale Commodities plants are covered by insurance obtained through NEIL’s
reinsurers.
Entergy maintains property insurance for its nuclear units in excess of the NRC’s minimum requirement of
$1.06 billion per site for nuclear power plant licensees. NRC regulations provide that the proceeds of this insurance
must be used, first, to render the reactor safe and stable, and second, to complete decontamination operations. Only
after proceeds are dedicated for such use and regulatory approval is secured would any remaining proceeds be made
available for the benefit of plant owners or their creditors.
In the event that one or more acts of terrorism causes property damage under one or more or all nuclear insurance
policies issued by NEIL (including, but not limited to, those described above) within 12 months from the date the first
property damage occurs, the maximum recovery under all such nuclear insurance policies shall be an aggregate of
$3.24 billion plus the additional amounts recovered for such losses from reinsurance, indemnity, and any other sources
applicable to such losses. The Terrorism Risk Insurance Reauthorization Act of 2007 created a government program
that provides for up to $100 billion in coverage in excess of existing coverage for a terrorist event. The Terrorism Risk
Insurance Reauthorization Act of 2007 expired on December 31, 2014. However, The Terrorism Risk Insurance
Reauthorization Act of 2015 was signed into law by the President of the United States on January 12, 2015 thereby
extending the Terrorism Risk Insurance Act for six years until December 31, 2020.
Conventional Property Insurance
Entergy’s conventional property insurance program provides coverage of up to $400 million on an Entergy
system-wide basis for all operational perils (direct physical loss or damage due to machinery breakdown, electrical
failure, fire, lightning, hail, or explosion) on an “each and every loss” basis; up to $400 million in coverage for certain
natural perils (direct physical loss or damage due to earthquake, tsunami, and flood) on an annual aggregate basis; up
to $125 million for certain other natural perils (direct physical loss or damage due to a named windstorm and associated
storm surge) on an annual aggregate basis; and up to $400 million in coverage for all other natural perils not previously
stated (direct physical loss or damage due to a tornado, ice storm, or any other natural peril except named windstorm
and associated storm surge, earthquake, tsunami, and flood) on an “each and every loss” basis. The conventional
property insurance program provides up to $50 million in coverage for the Entergy New Orleans gas distribution system
on an “each and every loss” basis. This $50 million limit is subject to: the $400 million annual aggregate limit for the
natural perils of earthquake, tsunami, and flood; the $125 million annual aggregate limit for the natural perils of named
windstorm and associated storm surge. The coverage is subject to a $40 million self-insured retention per occurrence
for the natural perils of named windstorm and associated storm surge, earthquake, flood, and tsunami; and a $20 million
155
E-5 Page 103 of 182
Entergy Corporation and Subsidiaries
Notes to Financial Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41
self-insured retention per occurrence for operational perils and all other natural perils not previously stated, which
includes tornado and ice storm, but excludes named windstorm and associated storm surge, earthquake, tsunami, and
flood.
Covered property generally includes power plants, substations, facilities, inventories, and gas distributionrelated properties. Excluded property generally includes above-ground transmission and distribution lines, poles, and
towers for substations valued at $5 million or less, coverage for named windstorm and associated storm surge is
excluded. This coverage is in place for Entergy Corporation, the Registrant Subsidiaries, and certain other Entergy
subsidiaries, including the owners of the nuclear power plants in the Entergy Wholesale Commodities segment. Entergy
also purchases $300 million in terrorism insurance coverage for its conventional property. The Terrorism Risk Insurance
Reauthorization Act of 2007 created a government program that provides for up to $100 billion in coverage in excess
of existing coverage for a terrorist event. The Terrorism Risk Insurance Reauthorization Act of 2007 expired on
December 31, 2014. However, The Terrorism Risk Insurance Reauthorization Act of 2015 was signed into law by the
President of the United States on January 12, 2015 thereby extending the Terrorism Risk Insurance Act for six years
until December 31, 2020.
In addition to the conventional property insurance program, Entergy has purchased additional coverage ($20
million per occurrence) for some of its non-regulated, non-generation assets. This policy serves to buy-down the $20
million deductible and is placed on a scheduled location basis. The applicable deductibles are $100,000 to $250,000,
except for properties that are damaged by flooding and properties whose values are greater than $20 million; these
properties have a $500,000 deductible. Four nuclear locations have a $2.5 million deductible, which coincides with
the nuclear property insurance deductible at each respective nuclear site.
Gas System Rebuild Insurance Proceeds (Entergy New Orleans)
Entergy New Orleans received insurance proceeds for future construction expenditures associated with
rebuilding its gas system, and the October 2006 City Council resolution approving the settlement of Entergy New
Orleans’s rate and storm-cost recovery filings requires Entergy New Orleans to record those proceeds in a designated
sub-account of other deferred credits until the proceeds are spent on the rebuild project. This other deferred credit is
shown as “Gas system rebuild insurance proceeds” on Entergy New Orleans’s balance sheet.
Employment and Labor-related Proceedings
The Registrant Subsidiaries and other Entergy subsidiaries are responding to various lawsuits in both state and
federal courts and to other labor-related proceedings filed by current and former employees, recognized bargaining
representatives, and third parties not selected for open positions or providing services directly or indirectly to one or
more of the Registrant Subsidiaries and other Entergy subsidiaries. Generally, the amount of damages being sought
is not specified in these proceedings. These actions include, but are not limited to, allegations of wrongful employment
actions; wage disputes and other claims under the Fair Labor Standards Act or its state counterparts; claims of race,
gender, age, and disability discrimination; disputes arising under collective bargaining agreements; unfair labor practice
proceedings and other administrative proceedings before the National Labor Relations Board or concerning the National
Labor Relations Act; claims of retaliation; claims of harassment and hostile work environment; and claims for or
regarding benefits under various Entergy Corporation-sponsored plans. Entergy and the Registrant Subsidiaries are
responding to these lawsuits and proceedings and deny liability to the claimants. Management believes that loss
exposure has been and will continue to be handled so that the ultimate resolution of these matters will not be material,
in the aggregate, to the financial position, results of operation, or cash flows of Entergy or the Utility operating
companies.
156
E-5 Page 104 of 182
Entergy Corporation and Subsidiaries
Notes to Financial
Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc.
41
Asbestos Litigation (Entergy Gulf States Louisiana, Entergy Louisiana, Entergy New Orleans, and Entergy
Texas)
Numerous lawsuits have been filed in federal and state courts primarily in Texas and Louisiana, primarily by
contractor employees who worked in the 1940-1980s timeframe, against Entergy Gulf States Louisiana and Entergy
Texas, and to a lesser extent the other Utility operating companies, as premises owners of power plants, for damages
caused by alleged exposure to asbestos. Many other defendants are named in these lawsuits as well. Currently, there
are approximately 400 lawsuits involving approximately 4,000 claimants. Management believes that adequate
provisions have been established to cover any exposure. Additionally, negotiations continue with insurers to recover
reimbursements. Management believes that loss exposure has been and will continue to be handled so that the ultimate
resolution of these matters will not be material, in the aggregate, to the financial position, results of operation, or cash
flows of the Utility operating companies.
Grand Gulf - Related Agreements
Capital Funds Agreement (Entergy Corporation and System Energy)
System Energy has entered into agreements with Entergy Arkansas, Entergy Louisiana, Entergy Mississippi,
and Entergy New Orleans whereby they are obligated to purchase their respective entitlements of capacity and energy
from System Energy’s interest in Grand Gulf, and to make payments that, together with other available funds, are
adequate to cover System Energy’s operating expenses. System Energy would have to secure funds from other sources,
including Entergy Corporation’s obligations under the Capital Funds Agreement, to cover any shortfalls from payments
received from Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans under these
agreements.
Unit Power Sales Agreement (Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans,
and System Energy)
System Energy has agreed to sell all of its share of capacity and energy from Grand Gulf to Entergy Arkansas,
Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans in accordance with specified percentages (Entergy
Arkansas-36%, Entergy Louisiana-14%, Entergy Mississippi-33%, and Entergy New Orleans-17%) as ordered by the
FERC. Charges under this agreement are paid in consideration for the purchasing companies’ respective entitlement
to receive capacity and energy and are payable irrespective of the quantity of energy delivered. The agreement will
remain in effect until terminated by the parties and the termination is approved by the FERC, most likely upon Grand
Gulf’s retirement from service. Monthly obligations are based on actual capacity and energy costs. The average
monthly payments for 2014 under the agreement are approximately $20.2 million for Entergy Arkansas, $8.0 million
for Entergy Louisiana, $17.4 million for Entergy Mississippi, and $9.8 million for Entergy New Orleans.
Availability Agreement (Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and
System Energy)
Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans are individually obligated
to make payments or subordinated advances to System Energy in accordance with stated percentages (Entergy
Arkansas-17.1%, Entergy Louisiana-26.9%, Entergy Mississippi-31.3%, and Entergy New Orleans-24.7%) in amounts
that, when added to amounts received under the Unit Power Sales Agreement or otherwise, are adequate to cover all
of System Energy’s operating expenses as defined, including an amount sufficient to amortize the cost of Grand Gulf
2 over 27 years (See Reallocation Agreement terms below) and expenses incurred in connection with a permanent
shutdown of Grand Gulf. System Energy has assigned its rights to payments and advances to certain creditors as
security for certain obligations. Since commercial operation of Grand Gulf began, payments under the Unit Power
Sales Agreement have exceeded the amounts payable under the Availability Agreement. Accordingly, no payments
under the Availability Agreement have ever been required. If Entergy Arkansas or Entergy Mississippi fails to make
its Unit Power Sales Agreement payments, and System Energy is unable to obtain funds from other sources, Entergy
157
E-5 Page 105 of 182
Entergy Corporation and Subsidiaries
Notes to Financial Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41
Louisiana and Entergy New Orleans could become subject to claims or demands by System Energy or its creditors for
payments or advances under the Availability Agreement (or the assignments thereof) equal to the difference between
their required Unit Power Sales Agreement payments and their required Availability Agreement payments.
Reallocation Agreement (Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans,
and System Energy)
System Energy, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans entered
into the Reallocation Agreement relating to the sale of capacity and energy from Grand Gulf and the related costs, in
which Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans agreed to assume all of Entergy Arkansas’s
responsibilities and obligations with respect to Grand Gulf under the Availability Agreement. FERC’s decision
allocating a portion of Grand Gulf capacity and energy to Entergy Arkansas supersedes the Reallocation Agreement
as it relates to Grand Gulf. Responsibility for any Grand Gulf 2 amortization amounts has been individually allocated
(Entergy Louisiana-26.23%, Entergy Mississippi-43.97%, and Entergy New Orleans-29.80%) under the terms of the
Reallocation Agreement. However, the Reallocation Agreement does not affect Entergy Arkansas’s obligation to
System Energy’s lenders under the assignments referred to in the preceding paragraph. Entergy Arkansas would be
liable for its share of such amounts if Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans were unable
to meet their contractual obligations. No payments of any amortization amounts will be required so long as amounts
paid to System Energy under the Unit Power Sales Agreement, including other funds available to System Energy,
exceed amounts required under the Availability Agreement, which is expected to be the case for the foreseeable future.
Reimbursement Agreement (System Energy)
In December 1988, in two separate but substantially identical transactions, System Energy sold and leased
back undivided ownership interests in Grand Gulf for the aggregate sum of $500 million. During the term of the leases,
System Energy is required to maintain letters of credit for the equity investors to secure certain amounts payable to
the equity investors under the transactions.
Under the provisions of the reimbursement agreement relating to the letters of credit, System Energy has agreed
to a number of covenants regarding the maintenance of certain capitalization and fixed charge coverage ratios. System
Energy agreed, during the term of the reimbursement agreement, to maintain a ratio of debt to total liabilities and equity
less than or equal to 70%. In addition, System Energy must maintain, with respect to each fiscal quarter during the
term of the reimbursement agreement, a ratio of adjusted net income to interest expense of at least 1.50 times earnings.
As of December 31, 2014, System Energy was in compliance with these covenants.
NOTE 9. ASSET RETIREMENT OBLIGATIONS (Entergy Corporation, Entergy Arkansas, Entergy Gulf
States Louisiana, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System
Energy)
Accounting standards require companies to record liabilities for all legal obligations associated with the
retirement of long-lived assets that result from the normal operation of the assets. For Entergy, substantially all of its
asset retirement obligations consist of its liability for decommissioning its nuclear power plants. In addition, an
insignificant amount of removal costs associated with non-nuclear power plants is also included in the decommissioning
line item on the balance sheets.
These liabilities are recorded at their fair values (which are the present values of the estimated future cash
outflows) in the period in which they are incurred, with an accompanying addition to the recorded cost of the longlived asset. The asset retirement obligation is accreted each year through a charge to expense, to reflect the time value
of money for this present value obligation. The accretion will continue through the completion of the asset retirement
activity. The amounts added to the carrying amounts of the long-lived assets will be depreciated over the useful lives
158
E-5 Page 106 of 182
Entergy Corporation and Subsidiaries
Notes to Financial
Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc.
41
of the assets. The application of accounting standards related to asset retirement obligations is earnings neutral to the
rate-regulated business of the Registrant Subsidiaries.
In accordance with ratemaking treatment and as required by regulatory accounting standards, the depreciation
provisions for the Registrant Subsidiaries include a component for removal costs that are not asset retirement obligations
under accounting standards. In accordance with regulatory accounting principles, the Registrant Subsidiaries have
recorded regulatory assets (liabilities) in the following amounts to reflect their estimates of the difference between
estimated incurred removal costs and estimated removal costs recovered in rates:
December 31,
2014
2013
(In Millions)
$59.0
$18.6
($36.9)
($35.3)
($45.7)
($37.0)
$76.3
$64.3
$35.2
$34.9
$18.9
$15.1
$55.7
$56.0
Entergy Arkansas
Entergy Gulf States Louisiana
Entergy Louisiana
Entergy Mississippi
Entergy New Orleans
Entergy Texas
System Energy
The cumulative decommissioning and retirement cost liabilities and expenses recorded in 2014 by Entergy
were as follows:
Utility:
Entergy Arkansas
Entergy Gulf States Louisiana
Entergy Louisiana
Entergy Mississippi
Entergy New Orleans
Entergy Texas
System Energy
Entergy Wholesale Commodities
Liabilities as
of December 31,
2013
Accretion
Change in
Cash Flow
Estimate
(In Millions)
$723.8
$403.1
$479.1
$6.4
$2.3
$4.3
$616.2
$1,698.2
$47.0
$23.5
$24.6
$0.4
$0.2
$0.3
$41.8
$139.7
$47.6
$20.0
$—
$—
$—
$—
$99.9
$101.6
159
Spending
$—
$—
$—
$—
$—
$—
$—
($21.7)
Liabilities as
of December 31,
2014
$818.4
$446.6
$503.7
$6.8
$2.5
$4.6
$757.9
$1,917.8
E-5 Page 107 of 182
Entergy Corporation and Subsidiaries
Notes to Financial Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41
The cumulative decommissioning and retirement cost liabilities and expenses recorded in 2013 by Entergy
were as follows:
Utility:
Entergy Arkansas
Entergy Gulf States Louisiana
Entergy Louisiana
Entergy Mississippi
Entergy New Orleans
Entergy Texas
System Energy
Entergy Wholesale Commodities
Liabilities as
of December 31,
2012
Accretion
$680.7
$380.8
$418.1
$6.0
$2.2
$4.1
$478.4
$1,543.3
$43.1
$22.3
$21.6
$0.4
$0.1
$0.2
$35.5
$125.3
Change in
Cash Flow
Estimate
Spending
(In Millions)
$—
$—
$39.4
$—
$—
$—
$102.3
$38.6
$—
$—
$—
$—
$—
$—
$—
($9.0)
Liabilities as
of December 31,
2013
$723.8
$403.1
$479.1
$6.4
$2.3
$4.3
$616.2
$1,698.2
Entergy periodically reviews and updates estimated decommissioning costs. The actual decommissioning costs may
vary from the estimates because of regulatory requirements, changes in technology, and increased costs of labor,
materials, and equipment. As described below, during 2014 and 2013 Entergy updated decommissioning cost estimates
for certain nuclear power plants.
In 2014, Entergy Arkansas recorded a revision to its estimated decommissioning cost liabilities for ANO 1 and
ANO 2 as a result of a revised decommissioning cost study. The revised estimates resulted in a $47.6 million increase
in the decommissioning cost liabilities, along with a corresponding increase in the related asset retirement cost assets
that will be depreciated over the remaining lives of the units.
See Note 1 to the financial statements for further discussion of the shutdown of Vermont Yankee and the
December 2013 settlement agreement involving Entergy and Vermont parties. In accordance with the settlement
agreement, Entergy Vermont Yankee provided to the Vermont parties, in 2014, a site assessment study of the costs and
tasks of radiological decommissioning, spent nuclear fuel management, and site restoration for Vermont Yankee.
Entergy Vermont Yankee also filed its Post-Shutdown Decommissioning Activities Report (PSDAR) for Vermont
Yankee with the NRC in December 2014. As part of the development of the site assessment study and PSDAR, Entergy
obtained a revised decommissioning cost study in the third quarter 2014. The revised estimate, along with reassessment
of the assumptions regarding the timing of decommissioning cash flows, resulted in a $101.6 million increase in the
decommissioning cost liability and a corresponding impairment charge.
In the fourth quarter 2014, Entergy Gulf States Louisiana recorded a revision to its estimated decommissioning
cost liability for River Bend as a result of a revised decommissioning cost study. The revised estimate resulted in a
$20 million increase in the decommissioning cost liability, along with a corresponding increase in the related asset
retirement cost asset that will be depreciated over the remaining useful life of the unit.
In the fourth quarter 2014, System Energy recorded a revision to its estimated decommissioning cost liability
for Grand Gulf as a result of a revised decommissioning cost study. The revised estimate resulted in a $99.9 million
increase in its decommissioning liability, along with a corresponding increase in the related asset retirement cost asset
that will be depreciated over the remaining life of the unit.
In the first quarter 2013, Entergy Wholesale Commodities recorded a revision to its estimated decommissioning
cost liability for a nuclear site as a result of a revised decommissioning cost study. The revised estimate resulted in a
$46.6 million reduction in the decommissioning cost liability, along with a corresponding reduction in the related asset
retirement cost asset.
160
E-5 Page 108 of 182
Entergy Corporation and Subsidiaries
Notes to Financial
Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc.
41
In the third quarter 2013, Entergy Wholesale Commodities recorded a revision to its estimated decommissioning
cost liability for Vermont Yankee as a result of a revised decommissioning cost study. The revised estimate resulted in
a $58 million increase in the decommissioning cost liability, along with a corresponding increase in the related asset
retirement cost asset. The increase in the estimated decommissioning cost liability resulted from the change in
expectation regarding the timing of decommissioning cash flows due to the decision to cease operations of the plant.
The asset retirement cost asset was included in the carrying value used to write down Vermont Yankee and related
assets to their fair values in third quarter 2013. See Note 1 to the financial statements for further discussion of the
resulting impairment charge recorded in third quarter 2013.
In the fourth quarter 2013, System Energy recorded a revision to its estimated decommissioning cost liability
for Grand Gulf as a result of a revised decommissioning cost study. The revised estimate resulted in a $102.3 million
increase in its decommissioning liability, along with a corresponding increase in the related asset retirement cost asset
that will be depreciated over the remaining life of the unit.
In the fourth quarter 2013, Entergy Louisiana recorded a revision to its estimated decommissioning cost liability
for Waterford 3 as a result of a revised decommissioning cost study. The revised estimate resulted in a $39.4 million
increase in its decommissioning cost liability, along with a corresponding increase in the related asset retirement cost
asset that will be depreciated over the remaining life of the unit.
In the fourth quarter 2013, Entergy Wholesale Commodities recorded a revision to its estimated
decommissioning cost liability for Vermont Yankee. As a result of the settlement agreement regarding the remaining
operation and decommissioning of Vermont Yankee, Entergy reassessed its assumptions regarding the timing of
decommissioning cash flows. The reassessment resulted in a $27.2 million increase in the decommissioning cost
liability and a corresponding impairment charge, which will not result in future cash expenditures. See Note 1 to the
financial statements for further discussion of the Vermont Yankee plant.
In the second quarter 2012, Entergy Wholesale Commodities recorded a reduction of $60.6 million in the
estimated decommissioning cost liability for a plant as a result of a revised decommissioning cost study. The revised
estimate resulted in a credit to decommissioning expense of $49 million, reflecting the excess of the reduction in the
liability over the amount of the undepreciated asset retirement costs asset.
Vermont Yankee submitted notification of permanent cessation of operations and permanent removal of fuel
from the reactor in January 2015 after final shutdown in December 2014. The PSDAR for Vermont Yankee, including
a site specific cost estimate, was submitted to the NRC in December 2014. Vermont Yankee’s future certifications to
satisfy the NRC’s financial assurance requirements will now be based on the site specific cost estimate, including the
estimated cost of managing spent fuel, rather than the NRC minimum formula for estimating decommissioning costs.
Entergy expects that amounts available in Vermont Yankee’s decommissioning trust fund, including expected earnings,
together with the credit facilities entered into in January 2015 that are expected to be repaid with recoveries from DOE
litigation related to spent fuel storage, will be sufficient to cover expected costs of decommissioning, spent fuel
management costs, and site restoration. Filings with the NRC for planned shutdown activities will determine whether
any other financial assurance may be required and will specifically address funding for spent fuel management, which
will be required until the federal government takes possession of the fuel and removes it from the site, per its current
obligation.
For the Indian Point 3 and FitzPatrick plants purchased in 2000, NYPA retained the decommissioning trusts
and the decommissioning liabilities. NYPA and Entergy subsidiaries executed decommissioning agreements, which
specify their decommissioning obligations. NYPA has the right to require the Entergy subsidiaries to assume each of
the decommissioning liabilities provided that it assigns the corresponding decommissioning trust, up to a specified
level, to the Entergy subsidiaries. If the decommissioning liabilities are retained by NYPA, the Entergy subsidiaries
will perform the decommissioning of the plants at a price equal to the lesser of a pre-specified level or the amount in
the decommissioning trusts. Entergy recorded an asset, which is $599.9 million as of December 31, 2014, representing
its estimate of the present value of the difference between the stipulated contract amount for decommissioning the
161
E-5 Page 109 of 182
Entergy Corporation and Subsidiaries
Notes to Financial Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41
plants less the decommissioning costs estimated in independent decommissioning cost studies. The asset is increased
by monthly accretion based on the applicable discount rate necessary to ultimately provide for the estimated future
value of the decommissioning contract. The monthly accretion is recorded as interest income.
Entergy maintains decommissioning trust funds that are committed to meeting its obligations for the costs of
decommissioning the nuclear power plants. The fair values of the decommissioning trust funds and the related asset
retirement obligation regulatory assets (liabilities) of Entergy as of December 31, 2014 are as follows:
Decommissioning
Regulatory
Trust Fair Values
Asset (Liability)
(In Millions)
Utility:
ANO 1 and ANO 2
River Bend
Waterford 3
Grand Gulf
Entergy Wholesale Commodities
$769.9
$637.7
$383.6
$679.8
$2,899.9
$247.6
($25.5)
$145.5
$80.4
$—
Entergy maintains decommissioning trust funds that are committed to meeting its obligations for the costs of
decommissioning the nuclear power plants. The fair values of the decommissioning trust funds and the related asset
retirement obligation regulatory assets (liabilities) of Entergy as of December 31, 2013 are as follows:
Decommissioning
Regulatory
Trust Fair Values
Asset (Liability)
(In Millions)
Utility:
ANO 1 and ANO 2
River Bend
Waterford 3
Grand Gulf
Entergy Wholesale Commodities
$710.9
$573.7
$347.3
$603.9
$2,667.3
162
$219.1
($28.7)
$128.5
$60.8
$—
E-5 Page 110 of 182
Entergy Corporation and Subsidiaries
Notes to Financial
Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc.
41
NOTE 10. LEASES (Entergy Corporation, Entergy Arkansas, Entergy Gulf States Louisiana, Entergy
Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)
General
As of December 31, 2014, Entergy had capital leases and non-cancelable operating leases for equipment,
buildings, vehicles, and fuel storage facilities with minimum lease payments as follows (excluding power purchase
agreement operating leases, nuclear fuel leases and the Grand Gulf and Waterford 3 sale and leaseback transactions,
all of which are discussed elsewhere):
Year
2015
2016
2017
2018
2019
Years thereafter
Minimum lease payments
Less: Amount representing interest
Present value of net minimum lease payments
Operating
Capital
Leases
Leases
(In Thousands)
$90,010
$4,615
77,060
4,457
62,103
4,457
49,630
3,672
47,527
2,887
95,530
27,664
421,860
47,752
—
15,773
$421,860
$31,979
Total rental expenses for all leases (excluding power purchase agreement operating leases, nuclear fuel leases
and the Grand Gulf and Waterford 3 sale and leaseback transactions) amounted to $59 million in 2014, $63.7 million
in 2013, and $69.9 million in 2012.
As of December 31, 2014 the Registrant Subsidiaries had a capital lease and non-cancelable operating leases
for equipment, buildings, vehicles, and fuel storage facilities with minimum lease payments as follows (excluding
power purchase agreement operating leases, nuclear fuel leases and the Grand Gulf and Waterford 3 sale and leaseback
transactions, all of which are discussed elsewhere):
Capital Leases
Entergy
Mississippi
Year
(in Thousands)
2015
2016
2017
2018
2019
Years thereafter
Minimum lease payments
Less: Amount representing interest
Present value of net minimum lease payments
163
$1,570
1,570
1,570
785
—
—
5,495
656
$4,839
E-5 Page 111 of 182
Entergy Corporation and Subsidiaries
Notes to Financial Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41
Operating Leases
Entergy
Arkansas
Year
2015
2016
2017
2018
2019
Years thereafter
Minimum lease payments
Entergy
Gulf States
Louisiana
$28,647
23,674
16,501
10,736
11,365
8,412
$99,335
$12,643
10,880
10,035
9,100
10,795
26,671
$80,124
Entergy
Entergy
Louisiana Mississippi
(In Thousands)
$11,006
$6,885
9,695
5,388
7,784
4,020
6,343
3,376
5,003
3,073
5,458
3,212
$45,289
$25,954
Entergy
New
Orleans
$2,115
1,856
1,587
1,264
1,087
2,227
$10,136
Entergy
Texas
$5,837
5,111
4,239
3,707
2,719
2,981
$24,594
Rental Expenses
Year
2014
2013
2012
Entergy
Arkansas
$12.0
$12.0
$12.6
Entergy
Gulf States
Louisiana
Entergy
Louisiana
$10.9
$10.9
$11.9
Entergy
Mississippi
(In Millions)
$9.8
$4.3
$10.1
$4.6
$11.2
$5.5
Entergy
New
Orleans
Entergy
Texas
$1.2
$1.3
$1.5
$3.8
$4.1
$6.4
System
Energy
$2.0
$2.5
$1.5
In addition to the above rental expense, railcar operating lease payments and oil tank facilities lease payments are
recorded in fuel expense in accordance with regulatory treatment. Railcar operating lease payments were $4.8 million
in 2014, $8.6 million in 2013, and $8.5 million in 2012 for Entergy Arkansas and $1.7 million in 2014, $2.2 million
in 2013, and $1.7 million in 2012 for Entergy Gulf States Louisiana. Oil tank facilities lease payments for Entergy
Mississippi were $1.6 million in 2014, $3.4 million in 2013, and $3.4 million in 2012.
Power Purchase Agreements
As of December 31, 2014, Entergy Texas had a power purchase agreement that is accounted for as an operating
lease under the accounting standards. The lease payments are recovered in fuel expense in accordance with regulatory
treatment. The minimum lease payments under the power purchase agreement are as follows:
Entergy
Texas (a)
Entergy
(In Thousands)
$28,450
$28,450
29,104
29,104
29,772
29,772
30,458
30,458
31,158
31,158
74,664
74,664
223,606
223,606
Year
2015
2016
2017
2018
2019
Years thereafter
Minimum lease payments
(a)
Amounts reflect 100% of minimum payments. Under a separate contract, Entergy Gulf States Louisiana
purchases 50% of the capacity and energy from the power purchase agreement from Entergy Texas.
164
E-5 Page 112 of 182
Entergy Corporation and Subsidiaries
Notes to Financial
Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc.
41
Total capacity expense under the power purchase agreement accounted for as an operating lease at Entergy Texas was
$29.2 million in 2014, $28.6 million in 2013, and $19.2 million in 2012.
Sale and Leaseback Transactions
Waterford 3 Lease Obligations
In 1989, in three separate but substantially identical transactions, Entergy Louisiana sold and leased back
undivided interests in Waterford 3 for the aggregate sum of $353.6 million. The leases expire in July 2017. At the
end of the lease terms, Entergy Louisiana has the option to repurchase the leased interests in Waterford 3 at fair market
value or to renew the leases for either fair market value or, under certain conditions, a fixed rate. In the event that
Entergy Louisiana does not renew or purchase the interests, Entergy Louisiana would surrender such interests and their
associated entitlement of Waterford 3’s capacity and energy.
Entergy Louisiana issued $208.2 million of non-interest bearing first mortgage bonds as collateral for the
equity portion of certain amounts payable under the leases.
Upon the occurrence of certain events, Entergy Louisiana may be obligated to assume the outstanding bonds
used to finance the purchase of the interests in the unit and to pay an amount sufficient to withdraw from the lease
transaction. Such events include lease events of default, events of loss, deemed loss events, or certain adverse “Financial
Events.” “Financial Events” include, among other things, failure by Entergy Louisiana, following the expiration of
any applicable grace or cure period, to maintain (i) total equity capital (including preferred membership interests) at
least equal to 30% of adjusted capitalization, or (ii) a fixed charge coverage ratio of at least 1.50 computed on a rolling
12 month basis. As of December 31, 2014, Entergy Louisiana was in compliance with these provisions.
As of December 31, 2014, Entergy Louisiana, in connection with the Waterford 3 sale and leaseback
transactions, had future minimum lease payments (reflecting an overall implicit rate of 7.45%) that are recorded as
long-term debt, as follows:
Amount
(In Thousands)
2015
2016
2017
2018
2019
Years thereafter
Total
Less: Amount representing interest
Present value of net minimum lease payments
$28,827
16,938
106,335
—
—
—
152,100
23,612
$128,488
Grand Gulf Lease Obligations
In 1988, in two separate but substantially identical transactions, System Energy sold and leased back undivided
ownership interests in Grand Gulf for the aggregate sum of $500 million. The initial term of the leases was to expire
in July 2015. In December 2013, System Energy exercised its options to renew the leases for fair market value with
a renewal term for one lease expiring in July 2018 and the renewal term of the other lease expiring in July 2036. At
the end of the new lease renewal terms, System Energy has the option to repurchase the leased interests in Grand Gulf
or renew the leases at fair market value. In the event that System Energy does not renew or purchase the interests,
System Energy would surrender such interests and their associated entitlement of Grand Gulf’s capacity and energy.
165
E-5 Page 113 of 182
Entergy Corporation and Subsidiaries
Notes to Financial Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41
System Energy is required to report the sale-leaseback as a financing transaction in its financial statements. For
financial reporting purposes, System Energy expenses the interest portion of the lease obligation and the plant
depreciation. However, operating revenues include the recovery of the lease payments because the transactions are
accounted for as a sale and leaseback for ratemaking purposes. Consistent with a recommendation contained in a
FERC audit report, System Energy initially recorded as a net regulatory asset the difference between the recovery of
the lease payments and the amounts expensed for interest and depreciation and continues to record this difference as
a regulatory asset or liability on an ongoing basis, resulting in a zero net balance for the regulatory asset at the end of
the lease term. The amount was a net regulatory liability of $62.9 million and $61.6 million as of December 31, 2014
and 2013, respectively.
As of December 31, 2014, System Energy, in connection with the Grand Gulf sale and leaseback transactions,
had future minimum lease payments (reflecting an implicit rate of 5.13%) that are recorded as long-term debt, as
follows:
Amount
(In Thousands)
2015
2016
2017
2018
2019
Years thereafter
Total
Less: Amount representing interest
Present value of net minimum lease payments
$52,253
13,750
13,750
13,750
13,750
233,750
341,003
290,332
$50,671
NOTE 11. RETIREMENT, OTHER POSTRETIREMENT BENEFITS, AND DEFINED CONTRIBUTION
PLANS (Entergy Corporation, Entergy Arkansas, Entergy Gulf States Louisiana, Entergy Louisiana, Entergy
Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)
Qualified Pension Plans
Entergy has nine qualified pension plans covering substantially all employees. The “Entergy Corporation
Retirement Plan for Non-Bargaining Employees,” “Entergy Corporation Retirement Plan for Bargaining Employees,”
“Entergy Corporation Retirement Plan II for Non-Bargaining Employees,” “Entergy Corporation Retirement Plan II
for Bargaining Employees,” “Entergy Corporation Retirement Plan IV for Non-Bargaining Employees,” and “Entergy
Corporation Retirement Plan IV for Bargaining Employees” are non-contributory final average pay plans and provide
pension benefits that are based on employees’ credited service and compensation during employment. The “Entergy
Corporation Retirement Plan III” is a final average pay plan that provides pension benefits that are based on employees’
credited service and compensation during the final years before retirement and includes a mandatory employee
contribution of 3% of earnings during the first 10 years of plan participation, and allows voluntary contributions from
1% to 10% of earnings for a limited group of employees. Non-bargaining employees hired or rehired after June 30,
2014 participate in the “Entergy Corporation Cash Balance Plan for Non-Bargaining Employees.” Certain bargaining
employees hired or rehired after June 30, 2014, or such later date provided for in their applicable collective bargaining
agreements, participate in the “Entergy Corporation Cash Balance Plan for Bargaining Employees.” The Registrant
Subsidiaries participate in these four plans: “Entergy Corporation Retirement Plan for Non-Bargaining Employees,”
“Entergy Corporation Retirement Plan for Bargaining Employees,” “Entergy Corporation Cash Balance Plan for NonBargaining Employees,” and “Entergy Cash Balance Plan for Bargaining Employees.”
166
E-5 Page 114 of 182
Entergy Corporation and Subsidiaries
Notes to Financial
Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc.
41
The assets of the seven final average pay qualified pension plans are held in a master trust established by
Entergy and the assets of the two cash balance pension plans are held in a second master trust established by
Entergy. Each pension plan has an undivided beneficial interest in each of the investment accounts in its respective
master trust that is maintained by a trustee. Use of the master trusts permits the commingling of the trust assets of the
pension plans of Entergy Corporation and its Registrant Subsidiaries for investment and administrative
purposes. Although assets in the master trusts are commingled, the trustee maintains supporting records for the purpose
of allocating the trust level equity in net earnings (loss) and the administrative expenses of the investment accounts in
each trust to the various participating pension plans in that particular trust. The fair value of the trusts’ assets is
determined by the trustee and certain investment managers. For each trust, the trustee calculates a daily earnings factor,
including realized and unrealized gains or losses, collected and accrued income, and administrative expenses, and
allocates earnings to each plan in the master trusts on a pro rata basis.
Within each pension plan, the record of each Registrant Subsidiary’s beneficial interest in the plan assets is
maintained by the plan’s actuary and is updated quarterly. Assets for each Registrant Subsidiary are increased for
investment income and contributions, and are decreased for benefit payments. A plan’s investment net income/loss
(i.e. interest and dividends, realized and unrealized gains and losses and expenses) is allocated to the Registrant
Subsidiaries participating in that plan based on the value of assets for each Registrant Subsidiary at the beginning of
the quarter adjusted for contributions and benefit payments made during the quarter.
Entergy Corporation and its subsidiaries fund pension costs in accordance with contribution guidelines
established by the Employee Retirement Income Security Act of 1974, as amended, and the Internal Revenue Code of
1986, as amended. The assets of the plans include common and preferred stocks, fixed-income securities, interest in
a money market fund, and insurance contracts. The Registrant Subsidiaries’ pension costs are recovered from customers
as a component of cost of service in each of their respective jurisdictions.
167
E-5 Page 115 of 182
Entergy Corporation and Subsidiaries
Notes to Financial Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41
Components of Qualified Net Pension Cost and Other Amounts Recognized as a Regulatory Asset and/or
Accumulated Other Comprehensive Income (AOCI)
Entergy Corporation and its subsidiaries’ total 2014, 2013, and 2012 qualified pension costs and amounts
recognized as a regulatory asset and/or other comprehensive income, including amounts capitalized, included the
following components:
2014
Net periodic pension cost:
Service cost - benefits earned during the period
Interest cost on projected benefit obligation
Expected return on assets
Amortization of prior service cost
Recognized net loss
Curtailment loss
Special termination benefit
Net periodic pension costs
Other changes in plan assets and benefit
obligations recognized as a regulatory
asset and/or AOCI (before tax)
Arising this period:
Net (gain)/loss
Amounts reclassified from regulatory asset and/or AOCI to net
periodic pension cost in the current year:
Amortization of prior service cost
Acceleration of prior service cost to curtailment
Amortization of net loss
Total
Total recognized as net periodic pension (income)/cost,
regulatory asset, and/or AOCI (before tax)
Estimated amortization amounts from regulatory asset and/or
AOCI to net periodic cost in the following year:
Prior service cost
Net loss
168
$140,436
290,076
(361,462)
1,600
145,095
—
732
$216,477
$1,389,912
(1,600)
—
(145,095)
1,243,217
$1,459,694
$1,561
$237,013
2013
(In Thousands)
2012
$172,280
263,296
(328,227)
2,125
213,194
16,318
13,139
$352,125
$150,763
260,929
(317,423)
2,733
167,279
—
—
$264,281
($894,150)
$552,303
(2,125)
(1,307)
(213,194)
(1,110,776)
(2,733)
—
(167,279)
382,291
($758,651)
$646,572
$1,600
$146,958
$2,268
$219,805
E-5 Page 116 of 182
Entergy Corporation and Subsidiaries
Notes to Financial
Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc.
41
The Registrant Subsidiaries’ total 2014, 2013, and 2012 qualified pension costs and amounts recognized as a
regulatory asset and/or other comprehensive income, including amounts capitalized, for their employees included the
following components:
2014
Entergy
Arkansas
Entergy
Gulf States
Louisiana
Entergy
Louisiana
Entergy
Mississippi
Entergy
New
Orleans
Entergy
Texas
System
Energy
(In Thousands)
Net periodic pension
cost:
Service cost - benefits
earned during the period
Interest cost on projected
benefit obligation
Expected return on assets
Amortization of prior
service cost
Recognized net loss
Net pension cost
Other changes in plan
assets and benefit
obligations recognized
as a regulatory asset
and/or AOCI (before
tax)
Arising this period:
Net loss
Amounts reclassified from
regulatory asset and/or
AOCI to net periodic
pension cost in the
current year:
Amortization of prior
service cost
Amortization of net
loss
Total
Total recognized as net
periodic pension
income regulatory
asset, and/or AOCI
(before tax)
Estimated amortization
amounts from
regulatory
asset and/or AOCI to
net periodic cost in the
following year
Net loss
$20,090
$11,524
$14,182
$6,094
$2,666
$5,142
$5,785
59,537
29,114
37,870
17,273
8,164
17,746
13,561
(73,218)
(37,950)
(45,796)
(22,794)
(10,019)
(23,723)
(16,619)
—
—
—
—
—
—
2
35,956
15,923
24,523
9,415
5,796
9,356
9,500
$42,365
$18,611
$30,779
$9,988
$6,607
$8,521
$12,229
$300,907
$125,090
$193,842
$88,199
$38,161
$65,363
$60,763
—
—
—
—
—
—
(24,523)
(9,415)
(5,796)
(9,356)
(2)
(35,956)
$264,951
(15,923)
$109,167
$169,319
$78,784
$32,365
$56,007
(9,500)
$51,261
$307,316
$127,778
$200,098
$88,772
$38,972
$64,528
$63,490
$54,254
$23,098
$36,704
$14,896
$8,053
$12,950
$13,055
169
E-5 Page 117 of 182
Entergy Corporation and Subsidiaries
Notes to Financial Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41
2013
Entergy
Arkansas
Entergy
Gulf States
Louisiana
Entergy
Louisiana
Entergy
Mississippi
Entergy
New
Orleans
Entergy
Texas
System
Energy
(In Thousands)
Net periodic pension cost:
Service cost - benefits earned
during the period
Interest cost on projected
benefit obligation
Expected return on assets
Amortization of prior service
cost
Recognized net loss
Curtailment loss
Special termination benefit
Net pension cost
Other changes in plan assets
and benefit obligations
recognized as a regulatory
asset and/or AOCI (before
tax)
Arising this period:
Net gain
Amounts reclassified from
regulatory asset and/or AOCI
to net periodic pension cost in
the current year:
Amortization of prior
service cost
Amortization of net loss
Total
Total recognized as net
periodic pension income,
regulatory asset, and/or
AOCI (before tax)
Estimated amortization
amounts from regulatory
asset and/or AOCI to net
periodic cost in the following
year
Prior service cost
Net loss
$25,229
$14,258
$17,044
$7,295
$3,264
$6,475
$7,242
54,473
26,741
34,857
15,802
7,462
16,303
12,170
(66,951)
(34,982)
(41,948)
(21,139)
(9,117)
(22,277)
(17,249)
23
9
83
10
2
6
9
49,517
23,374
34,107
13,189
7,878
13,302
9,560
4,938
805
3,542
767
343
1,559
—
1,784
$69,013
808
$31,013
1,631
$49,316
359
$16,283
581
$10,413
855
$16,223
1,970
$13,702
($177,105)
($98,610) ($123,234)
($25,419) ($55,772) ($35,511)
(83)
(10)
(49,517)
($226,645)
(23,374)
(34,107)
($121,993) ($157,424)
(13,189)
($65,724)
(7,878) (13,302)
(9,560)
($33,299) ($69,080) ($45,080)
($157,632)
($90,980) ($108,108)
($49,441)
($22,886) ($52,857) ($31,378)
(23)
$—
$35,984
(9)
($52,525)
$—
$15,935
170
$—
$24,360
$—
$9,421
(2)
$—
$5,802
(6)
$—
$9,363
(9)
$2
$9,510
E-5 Page 118 of 182
Entergy Corporation and Subsidiaries
Notes to Financial
Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc.
41
2012
Entergy
Arkansas
Entergy
Gulf States
Louisiana
Entergy
Louisiana
Entergy
Mississippi
Entergy
New
Orleans
Entergy
Texas
System
Energy
(In Thousands)
Net periodic pension cost:
Service cost - benefits earned
during the period
Interest cost on projected
benefit obligation
Expected return on assets
Amortization of prior service
cost
Recognized net loss
Net pension cost
Other changes in plan assets
and benefit obligations
recognized as a regulatory
asset and/or AOCI (before
tax)
Arising this period:
Net loss
Amounts reclassified from
regulatory asset and/or AOCI
to net periodic pension cost in
the current year:
Amortization of prior service
cost
Amortization of net loss
Total
Total recognized as net
periodic pension cost,
regulatory asset, and/or
AOCI (before tax)
Estimated amortization
amounts from regulatory
asset and/or AOCI to net
periodic cost in the
following year
Prior service cost
Net loss
$22,169
$12,273
$14,675
$6,410
$2,824
$5,684
$5,920
55,686
25,679
35,201
16,279
7,608
16,823
12,987
(65,763)
(34,370)
(40,836)
(20,945)
(8,860)
(22,325)
(16,436)
200
19
208
30
7
15
13
40,772
16,173
28,197
10,532
6,878
10,179
9,001
$53,064
$19,774
$37,445
$12,306
$8,457
$10,376
$11,485
$105,133
$77,207
$76,163
$27,106
$14,282
$28,745
$10,266
(200)
(19)
(208)
(30)
(7)
(15)
(13)
(40,772)
$64,161
(16,173)
(28,197)
(10,532)
(6,878)
(10,179)
$61,015
$47,758
$16,544
$7,397
$18,551
(9,001)
$1,252
$117,225
$80,789
$85,203
$28,850
$15,854
$28,927
$12,737
$23
$50,175
$9
$23,731
$83
$34,906
$10
$13,375
$2
$8,046
$6
$13,494
$10
$9,717
171
E-5 Page 119 of 182
Entergy Corporation and Subsidiaries
Notes to Financial Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41
Qualified Pension Obligations, Plan Assets, Funded Status, Amounts Recognized in the Balance Sheet for
Entergy Corporation and its Subsidiaries as of December 31, 2014 and 2013
December 31,
2014
2013
(In Thousands)
Change in Projected Benefit Obligation (PBO)
Balance at beginning of year
Service cost
Interest cost
Curtailment
Special termination benefit
Actuarial loss/(gain)
Employee contributions
Benefits paid
Balance at end of year
Change in Plan Assets
Fair value of assets at beginning of year
Actual return on plan assets
Employer contributions
Employee contributions
Benefits paid
Fair value of assets at end of year
Funded status
Amount recognized in the balance sheet
Non-current liabilities
Amount recognized as a regulatory asset
Prior service cost
Net loss
Amount recognized as AOCI (before tax)
Prior service cost
Net loss
172
$5,770,999
140,436
290,076
—
732
1,284,049
560
(256,310)
$7,230,542
$6,096,639
172,280
263,296
15,011
13,139
(571,990)
598
(217,974)
$5,770,999
$4,429,237
255,599
398,880
560
(256,310)
$4,827,966
($2,402,576)
$3,832,860
650,386
163,367
598
(217,974)
$4,429,237
($1,341,762)
($2,402,576)
($1,341,762)
$3,704
2,451,172
$2,454,876
$5,027
1,494,117
$1,499,144
$1,015
671,682
$672,697
$1,292
383,920
$385,212
E-5 Page 120 of 182
Entergy Corporation and Subsidiaries
Notes to Financial
Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc.
41
Qualified Pension Obligations, Plan Assets, Funded Status, and Amounts Recognized in the Balance Sheet for
the Registrant Subsidiaries as of December 31, 2014 and 2013
2014
Change in Projected
Benefit Obligation (PBO)
Balance at beginning of year
Service cost
Interest cost
Actuarial loss
Benefits paid
Balance at end of year
Change in Plan Assets
Fair value of assets at
beginning of year
Actual return on plan assets
Employer contributions
Benefits paid
Fair value of assets at end of
year
Funded status
Amounts recognized in the
balance sheet (funded
status)
Non-current liabilities
Amounts recognized as
regulatory asset
Net loss
Amounts recognized as
AOCI (before tax)
Net loss
Entergy
Gulf
States
Louisiana
Entergy
Louisiana
$1,192,640
$579,862
$761,350
20,090
11,524
59,537
279,781
Entergy
New
Orleans
Entergy
Texas
System
Energy
$345,824
$163,707
$356,080
$270,789
14,182
6,094
2,666
5,142
5,785
29,114
37,870
17,273
8,164
17,746
13,561
113,883
180,763
81,600
35,131
58,556
55,410
(66,330)
$1,485,718
(24,389)
$709,994
(37,624)
$956,541
(18,622)
$432,169
(7,113)
$202,555
(19,026)
$418,498
(11,233)
$334,312
$896,295
$469,295
$561,892
$281,837
$122,960
$295,751
$196,328
52,092
26,744
32,716
16,196
6,988
16,916
11,265
95,464
30,176
54,549
21,839
10,509
17,072
21,261
(66,330)
(24,389)
(37,624)
(18,622)
(7,113)
(19,026)
(11,233)
$977,521
($508,197)
$501,826
($208,168)
$611,533
($345,008)
$301,250
($130,919)
$133,344
($69,211)
$310,713
($107,785)
$217,621
($116,691)
($508,197)
($208,168)
($345,008)
($130,919)
($69,211)
($107,785)
($116,691)
$722,119
$272,695
$468,779
$198,972
$102,141
$176,522
$172,463
$—
$40,748
$—
$—
$—
$—
$—
Entergy
Arkansas
173
Entergy
Mississippi
(In Thousands)
E-5 Page 121 of 182
Entergy Corporation and Subsidiaries
Notes to Financial Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41
2013
Change in Projected
Benefit Obligation (PBO)
Balance at beginning of
year
Service cost
Interest cost
Curtailment
Special termination benefit
Actuarial gain
Benefits paid
Balance at end of year
Change in Plan Assets
Fair value of assets at
beginning of year
Actual return on plan assets
Employer contributions
Benefits paid
Fair value of assets at end
of year
Funded status
Amounts recognized in
the balance sheet (funded
status)
Non-current liabilities
Amounts recognized as
regulatory asset
Prior service cost
Net loss
Entergy
Arkansas
Entergy
Gulf States
Louisiana
Entergy
Louisiana
Entergy
New
Orleans
Entergy
Texas
System
Energy
$1,274,886
$623,068
$817,745
$369,852
$174,585
$382,176
$282,841
25,229
14,258
17,044
7,295
3,264
6,475
7,242
54,473
26,741
34,857
15,802
7,462
16,303
12,170
4,938
805
3,542
767
343
1,559
—
1,784
808
1,631
359
581
855
1,970
Entergy
Mississippi
(In Thousands)
(110,943)
(64,119)
(80,794)
(31,684)
(16,276)
(33,792)
(23,882)
(57,727)
$1,192,640
(21,699)
$579,862
(32,675)
(16,567)
(6,252)
(17,496)
$761,350
$345,824
$163,707
$356,080
(9,552)
$270,789
$785,527
$409,971
$489,027
$248,272
$106,778
$262,110
$168,697
133,113
69,473
84,388
41,980
18,259
44,257
28,878
35,382
11,550
21,152
8,152
4,175
6,880
8,305
(57,727)
(21,699)
(32,675)
(16,567)
(6,252)
(17,496)
(9,552)
$896,295
($296,345)
$469,295
$561,892
($110,567) ($199,458)
$281,837
($63,987)
$122,960
($40,747)
$295,751
($60,329)
$196,328
($74,461)
($296,345)
($110,567) ($199,458)
($63,987)
($40,747)
($60,329)
($74,461)
$—
$—
457,485
178,990
$457,485
$—
Amounts recognized as
AOCI (before tax)
Net loss
($1)
$—
$—
$—
($4)
299,740
120,290
69,856
120,619
121,327
$178,990
$299,739
$120,290
$69,856
$120,619
$121,323
$25,437
$—
$—
$—
$—
$—
Other Postretirement Benefits
Entergy also currently offers retiree medical, dental, vision, and life insurance benefits (other postretirement
benefits) for eligible retired employees. Employees who commenced employment before July 1, 2014 and who satisfy
certain eligibility requirements (including retiring from Entergy after a certain age and/or years of service with Entergy
and immediately commencing their Entergy pension benefit), may become eligible for other postretirement benefits.
In December 2013, Entergy announced changes to its other postretirement benefits which include, among other
things, elimination of other postretirement benefits for all non-bargaining employees hired or rehired after June 30,
2014 and for certain bargaining employees hired or rehired after June 30, 2014, or such later date provided for in their
applicable collective bargaining agreement, and setting a dollar limit cap on Entergy’s contribution to retiree medical
costs, effective 2019 for those non-bargaining employees who commence their Entergy retirement benefits on or after
174
E-5 Page 122 of 182
Entergy Corporation and Subsidiaries
Notes to Financial
Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc.
41
January 1, 2015 and for certain bargaining employees who commence their Entergy retirement benefits on or after
January 1, 2015 or such later date as provided for in their applicable collective bargaining agreement. In accordance
with accounting standards, certain of the other postretirement benefit changes have been reflected in the December
31, 2013 other postretirement obligation. The changes affecting active bargaining unit employees are being negotiated
with the unions prior to implementation, where necessary, and to the extent required by law.
Entergy uses a December 31 measurement date for its postretirement benefit plans.
Effective January 1, 1993, Entergy adopted an accounting standard requiring a change from a cash method to
an accrual method of accounting for postretirement benefits other than pensions. At January 1, 1993, the actuarially
determined accumulated postretirement benefit obligation (APBO) earned by retirees and active employees was
estimated to be approximately $241.4 million for Entergy (other than the former Entergy Gulf States) and $128 million
for the former Entergy Gulf States (now split into Entergy Gulf States Louisiana and Entergy Texas). Such obligations
were being amortized over a 20-year period that began in 1993 and ended in 2012. For the most part, the Registrant
Subsidiaries recover accrued other postretirement benefit costs from customers and are required to contribute the other
postretirement benefits collected in rates to an external trust.
Entergy Arkansas, Entergy Mississippi, Entergy New Orleans, and Entergy Texas have received regulatory
approval to recover accrued other postretirement benefit costs through rates. Entergy Arkansas began recovery in
1998, pursuant to an APSC order. This order also allowed Entergy Arkansas to amortize a regulatory asset (representing
the difference between other postretirement benefit costs and cash expenditures for other postretirement benefits
incurred from 1993 through 1997) over a 15-year period that began in January 1998 and ended in December 2012.
The LPSC ordered Entergy Gulf States Louisiana and Entergy Louisiana to continue the use of the pay-asyou-go method for ratemaking purposes for postretirement benefits other than pensions. However, the LPSC retains
the flexibility to examine individual companies’ accounting for other postretirement benefits to determine if special
exceptions to this order are warranted.
Pursuant to regulatory directives, Entergy Arkansas, Entergy Mississippi, Entergy New Orleans, Entergy Texas,
and System Energy contribute the other postretirement benefit costs collected in rates into external trusts. System
Energy is funding, on behalf of Entergy Operations, other postretirement benefits associated with Grand Gulf.
Trust assets contributed by participating Registrant Subsidiaries are in bank-administered master trusts,
established by Entergy Corporation and maintained by a trustee. Each participating Registrant Subsidiary holds a
beneficial interest in the trusts’ assets. The assets in the master trusts are commingled for investment and administrative
purposes. Although assets are commingled, supporting records are maintained for the purpose of allocating the
beneficial interest in net earnings/(losses) and the administrative expenses of the investment accounts to the various
participating plans and participating Registrant Subsidiaries. Beneficial interest in an investment account’s net income/
(loss) is comprised of interest and dividends, realized and unrealized gains and losses, and expenses. Beneficial interest
from these investments is allocated to the plans and participating Registrant Subsidiary based on their portion of net
assets in the pooled accounts.
175
E-5 Page 123 of 182
Entergy Corporation and Subsidiaries
Notes to Financial Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41
Components of Net Other Postretirement Benefit Cost and Other Amounts Recognized as a Regulatory Asset
and/or AOCI
Entergy Corporation’s and its subsidiaries’ total 2014, 2013, and 2012 other postretirement benefit costs,
including amounts capitalized and amounts recognized as a regulatory asset and/or other comprehensive income,
included the following components:
2014
Other postretirement costs:
Service cost - benefits earned during the period
Interest cost on APBO
Expected return on assets
Amortization of transition obligation
Amortization of prior service credit
Recognized net loss
Curtailment loss
Net other postretirement benefit cost
Other changes in plan assets and benefit
obligations recognized as a regulatory asset
and /or AOCI (before tax)
Arising this period:
Prior service credit for period
Net loss/(gain)
Amounts reclassified from regulatory asset and /or AOCI to net
periodic benefit cost in the current year:
Amortization of transition obligation
Amortization of prior service credit
Acceleration of prior service credit due to curtailment
Amortization of net loss
Total
Total recognized as net periodic benefit income/(cost),
regulatory asset, and/or AOCI (before tax)
Estimated amortization amounts from regulatory asset and/or
AOCI to net periodic benefit cost in the following year
Prior service credit
Net loss
176
2013
(In Thousands)
2012
$43,493
71,841
(44,787)
—
(31,590)
11,143
—
$50,100
$74,654
79,453
(40,323)
—
(14,904)
44,178
12,729
$155,787
$68,883
82,561
(34,503)
3,177
(18,163)
36,448
—
$138,403
($35,864)
287,313
($116,571)
(405,976)
$—
92,584
—
31,590
—
(11,143)
$271,896
—
14,904
1,989
(44,178)
($549,832)
(3,177)
18,163
—
(36,448)
$71,122
$321,996
($394,045)
$209,525
($37,280)
$31,591
($31,589)
$11,197
($13,336)
$45,217
E-5 Page 124 of 182
Entergy Corporation and Subsidiaries
Notes to Financial
Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc.
41
Total 2014, 2013, and 2012 other postretirement benefit costs of the Registrant Subsidiaries, including amounts
capitalized and deferred, for their employees included the following components:
2014
Other postretirement
costs:
Service cost - benefits
earned during the period
Interest cost on APBO
Expected return on assets
Amortization of prior credit
Recognized net loss
Net other postretirement
benefit (income)/cost
Other changes in plan
assets and benefit
obligations recognized as
a regulatory asset and/or
AOCI (before tax)
Arising this period:
Prior service credit for
the period
Net loss
Amounts reclassified from
regulatory asset and/or
AOCI to net periodic
pension cost in the current
year:
Amortization of prior
service credit
Amortization of net loss
Total
Total recognized as net
periodic other
postretirement income,
regulatory asset, and/or
AOCI (before tax)
Estimated amortization
amounts from regulatory
asset and/or AOCI to net
periodic cost in the
following year
Prior service credit
Net loss
Entergy
Arkansas
Entergy
Gulf States
Louisiana
Entergy
Entergy
Louisiana Mississippi
(In Thousands)
$5,957
12,261
(19,135)
$4,896
8,378
—
$4,518
8,264
—
(2,441)
1,267
(2,237)
1,212
(3,377)
1,511
Entergy
New
Orleans
Entergy
Texas
System
Energy
$1,900
3,655
(5,771)
$868
2,805
(4,475)
$2,378
5,652
(10,358)
$2,058
2,611
(3,727)
(915)
149
(709)
56
(1,300)
801
(824)
443
($982)
($1,455)
($2,827)
$561
$—
$6,309
($8,536)
($3,845)
$24,482
$10,596
($2,091)
$12,249
$10,916
$—
$55,642
($12,845)
$36,467
$—
$24,582
2,441
(1,267)
$56,816
2,237
(1,212)
$24,647
$26,448
$10,291
$6,962
$16,445
$7,132
$54,725
$36,896
$37,364
$9,309
$5,507
$13,618
$7,693
($2,441)
$5,356
($4,086)
$3,908
($3,381)
($916)
($709)
($2,723)
($1,465)
$3,210
$860
$470
$2,740
$1,198
3,377
(1,511)
177
$—
$9,525
915
(149)
709
(56)
1,300
(801)
824
(443)
E-5 Page 125 of 182
Entergy Corporation and Subsidiaries
Notes to Financial Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41
2013
Other postretirement costs:
Service cost - benefits earned
during the period
Interest cost on APBO
Expected return on assets
Amortization of prior credit
Recognized net loss
Curtailment loss
Entergy
Arkansas
Entergy
Gulf States
Louisiana
$9,619
$7,910
$8,541
$3,246
$1,752
$3,760
$3,580
13,545
(16,843)
8,964
9,410
4,289
3,135
6,076
2,945
—
—
(5,335)
(4,101)
(9,391)
(3,350)
(942)
(508)
(204)
(24)
(501)
(126)
Entergy
Entergy
Louisiana Mississippi
(In Thousands)
Entergy
New
Orleans
Entergy
Texas
System
Energy
(689)
7,976
4,598
5,050
2,534
1,509
3,744
1,896
4,517
1,546
1,848
596
354
1,436
760
$18,125
$22,076
$24,341
$5,126
$2,625
$5,124
$5,705
($11,617)
($8,705)
($18,844)
($4,714)
($4,469)
($5,359)
($4,591)
Net loss
Amounts reclassified from
regulatory asset and/or AOCI
to net periodic pension cost in
the current year:
Amortization of prior service
credit
Acceleration of prior service
credit/(cost) due to curtailment
Amortization of net loss
($81,236)
($40,938)
($43,743)
($30,018)
(7,976)
(4,598)
(5,050)
(2,534)
Total
Total recognized as net
periodic other
postretirement cost,
regulatory asset, and/or
AOCI (before tax)
Estimated amortization
amounts from regulatory
asset and/or AOCI to net
periodic cost in the following
year
Prior service credit
Net loss
($100,062)
($53,208)
($67,088)
($37,042)
($24,466) ($43,102) ($23,931)
($81,937)
($31,132)
($42,747)
($31,916)
($21,841) ($37,978) ($18,226)
($2,441)
($2,236)
($3,376)
($918)
($709)
$1,267
$1,212
$1,511
$149
$56
Net other postretirement benefit
cost
Other changes in plan assets
and benefit obligations
recognized as a regulatory
asset and/or AOCI (before
tax)
Arising this period:
Prior service credit for the
period
($18,508) ($34,562) ($17,579)
689
942
508
204
24
501
126
78
91
41
20
(4)
62
9
178
(1,509)
(3,744)
($1,301)
$800
(1,896)
($824)
$464
E-5 Page 126 of 182
Entergy Corporation and Subsidiaries
Notes to Financial
Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc.
41
2012
Other postretirement
costs:
Service cost - benefits
earned during the period
Interest cost on APBO
Expected return on assets
Amortization of transition
obligation
Amortization of prior
service cost/(credit)
Recognized net loss
Net other postretirement
benefit cost
Other changes in plan
assets and benefit
obligations recognized as
a regulatory asset and/or
AOCI (before tax)
Arising this period:
Net loss
Amounts reclassified from
regulatory asset and/or
AOCI to net periodic
pension cost in the current
year:
Amortization of transition
obligation
Amortization of prior
service (cost)/credit
Amortization of net loss
Total
Total recognized as net
periodic other
postretirement income,
regulatory asset, and/or
AOCI (before tax)
Estimated amortization
amounts from regulatory
asset and/or AOCI to net
periodic cost in the
following year
Prior service cost/
(credit)
Net loss
Entergy
Arkansas
Entergy
Gulf States
Louisiana
$9,089
$7,521
$7,796
$3,093
$1,689
$3,651
$3,293
14,452
(14,029)
9,590
9,781
4,716
3,422
6,650
3,028
—
—
(4,521)
(3,711)
(8,415)
(2,601)
820
238
382
351
(530)
8,305
(824)
(247)
(139)
Entergy
Entergy
Louisiana Mississippi
(In Thousands)
Entergy
New
Orleans
1,189
38
Entergy
Texas
System
Energy
187
8
(428)
(63)
4,737
4,359
2,920
1,559
4,320
1,970
$18,107
$21,262
$22,071
$6,420
$4,186
$5,965
$5,635
$9,066
$5,818
$16,215
$271
$2,260
$191
$2,043
(1,189)
(187)
(8)
428
63
(820)
(238)
(382)
(351)
530
824
247
139
(8,305)
(4,737)
$471
$1,667
$18,578
$22,929
($530)
$8,163
(4,359)
(2,920)
(1,559)
(4,320)
(1,970)
$11,721
($2,861)
($526)
($3,888)
$128
$33,792
$3,559
($247)
($824)
$4,693
$5,149
179
(38)
($139)
$2,650
$3,660
$38
$1,587
$2,077
($428)
$3,905
$5,763
($62)
$1,915
E-5 Page 127 of 182
Entergy Corporation and Subsidiaries
Notes to Financial Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41
Other Postretirement Benefit Obligations, Plan Assets, Funded Status, and Amounts Not Yet Recognized and
Recognized in the Balance Sheet of Entergy Corporation and its Subsidiaries as of December 31, 2014 and 2013
December 31,
2014
2013
(In Thousands)
Change in APBO
Balance at beginning of year
Service cost
Interest cost
Plan amendments
Curtailment
Plan participant contributions
Actuarial loss/(gain)
Benefits paid
Medicare Part D subsidy received
Balance at end of year
Change in Plan Assets
Fair value of assets at beginning of year
Actual return on plan assets
Employer contributions
Plan participant contributions
Benefits paid
Fair value of assets at end of year
Funded status
Amounts recognized in the balance sheet
Current liabilities
Non-current liabilities
Total funded status
Amounts recognized as a regulatory asset
Prior service credit
Net loss
Amounts recognized as AOCI (before tax)
Prior service credit
Net loss
180
$1,461,910
43,493
71,841
(35,864)
—
22,160
274,061
(102,439)
4,395
$1,739,557
$1,846,922
74,654
79,453
(116,571)
14,718
19,141
(370,004)
(89,713)
3,310
$1,461,910
$569,850
31,535
76,521
22,160
(102,439)
$597,627
($1,141,930)
$488,448
76,314
75,660
19,141
(89,713)
$569,850
($892,060)
($41,821)
(1,100,109)
($1,141,930)
($40,602)
(851,458)
($892,060)
($54,508)
248,918
$194,410
($93,332)
165,270
$71,938
($104,086)
300,518
$196,432
($60,988)
107,996
$47,008
E-5 Page 128 of 182
Entergy Corporation and Subsidiaries
Notes to Financial
Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc.
41
Other Postretirement Benefit Obligations, Plan Assets, Funded Status, and Amounts Not Yet Recognized and
Recognized in the Balance Sheets of the Registrant Subsidiaries as of December 31, 2014 and 2013
2014
Entergy
Arkansas
Entergy
Gulf States
Louisiana
Entergy
Louisiana
Entergy
Mississippi
Entergy
New
Orleans
Entergy
Texas
System
Energy
(In Thousands)
Change in APBO
Balance at beginning of year
Service cost
Interest cost
Plan amendments
Plan participant
contributions
Actuarial loss
Benefits paid
Medicare Part D subsidy
received
Balance at end of year
Change in Plan Assets
Fair value of assets at
beginning of year
Actual return on plan assets
Employer contributions
Plan participant
contributions
Benefits paid
Fair value of assets at end of
year
Funded status
Amounts recognized in the
balance sheet
Current liabilities
Non-current liabilities
Total funded status
Amounts recognized in
regulatory asset
Prior service credit
Net loss
Amounts recognized in
AOCI (before tax)
Prior service credit
Net loss
$250,734
$170,302
$168,764
$74,539
$57,874
$115,418
$53,051
5,957
4,896
4,518
1,900
868
2,378
2,058
12,261
8,378
8,264
3,655
2,805
5,652
2,611
—
—
—
(8,536)
(3,845)
—
(12,845)
5,195
2,304
2,767
1,396
1,044
1,655
1,061
49,573
36,467
24,582
7,939
5,097
21,471
9,524
(20,984)
(10,613)
(14,012)
(6,589)
(4,131)
(8,333)
(3,858)
980
520
654
322
222
440
152
$303,716
$199,409
$195,537
$83,162
$63,779
$130,145
$60,754
$231,663
$—
$—
$73,438
$66,539
$131,618
$48,101
13,066
—
—
4,185
3,263
7,347
2,655
15,251
8,309
11,245
8,505
4,289
3,446
334
5,195
2,304
2,767
1,396
1,044
1,655
1,061
(20,984)
(10,613)
(14,012)
(6,589)
(4,131)
(8,333)
(3,858)
$244,191
($59,525)
$—
($199,409)
$—
($195,537)
$80,935
($2,227)
($8,884)
($9,840)
(59,525)
(190,525)
(185,697)
($59,525)
($199,409)
($195,537)
$—
$71,004
$7,225
$135,733
$5,588
$—
$—
(2,227)
7,225
5,588
(12,461)
($2,227)
$7,225
$5,588
($12,461)
$—
$48,293
($12,461)
$—
($10,555)
$—
$—
($4,141)
($3,626)
($13,741)
($7,723)
94,647
—
—
18,680
12,738
46,453
20,450
$84,092
$—
$—
$14,539
$9,112
$32,712
$12,727
$—
($20,967)
($16,013)
$—
$—
$—
$—
—
66,832
58,072
—
—
—
—
$—
$45,865
$42,059
$—
$—
$—
$—
181
E-5 Page 129 of 182
Entergy Corporation and Subsidiaries
Notes to Financial Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41
2013
Entergy
Arkansas
Entergy
Gulf States
Louisiana
Entergy
Louisiana
Entergy
Mississippi
Entergy
New
Orleans
Entergy
Texas
System
Energy
(In Thousands)
Change in APBO
Balance at beginning of year
Service cost
Interest cost
Plan amendments
Curtailment
Plan participant
contributions
Actuarial gain
Benefits paid
Medicare Part D subsidy
received
Balance at end of year
Change in Plan Assets
Fair value of assets at
beginning of year
Actual return on plan assets
Employer contributions
Plan participant
contributions
Benefits paid
Fair value of assets at end of
year
Funded status
Amounts recognized in the
balance sheet
Current liabilities
Non-current liabilities
Total funded status
Amounts recognized in
regulatory asset
Prior service credit
Net loss
Amounts recognized in
AOCI (before tax)
Prior service credit
Net loss
$315,308
$207,987
$220,017
$100,508
$74,200
$142,114
$67,934
9,619
7,910
8,541
3,246
1,752
3,760
3,580
13,545
8,964
9,410
4,289
3,135
6,076
2,945
(11,617)
(8,705)
(18,844)
(4,714)
(4,469)
(5,359)
(4,591)
4,595
1,637
1,889
616
350
1,498
769
4,564
1,998
2,509
1,292
915
1,498
860
(67,253)
(40,941)
(43,747)
(25,527)
(13,739)
(26,048)
(14,639)
(18,764)
(8,958)
(11,524)
(5,416)
(4,464)
(8,455)
(3,912)
737
410
513
245
194
334
105
$250,734
$170,302
$168,764
$74,539
$57,874
$115,418
$53,051
$194,018
$—
$—
$62,951
$58,651
$115,824
$39,474
30,830
—
—
9,826
8,870
17,905
6,292
21,015
6,960
9,015
4,785
2,567
4,846
5,387
4,564
1,998
2,509
1,292
915
1,498
860
(18,764)
(8,958)
(11,524)
(5,416)
$231,663
($19,071)
$—
($170,302)
$—
($168,764)
$73,438
($1,101)
($8,803)
($10,249)
(19,071)
(161,499)
(158,515)
($19,071)
($170,302)
($168,764)
$—
(4,464)
(8,455)
(3,912)
$66,539
$8,665
$131,618
$16,200
$—
$—
(1,101)
8,665
16,200
(4,950)
($1,101)
$8,665
$16,200
($4,950)
$—
$48,101
($4,950)
$—
($12,996)
$—
$—
($5,056)
($4,335)
($6,505)
($4,702)
40,272
—
—
9,304
6,485
22,772
10,297
$27,276
$—
$—
$4,248
$2,150
$16,267
$5,595
$—
($10,359)
($19,390)
$—
$—
$—
$—
—
31,577
35,001
—
—
—
—
$—
$21,218
$15,611
$—
$—
$—
$—
182
E-5 Page 130 of 182
Entergy Corporation and Subsidiaries
Notes to Financial
Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc.
41
Non-Qualified Pension Plans
Entergy also sponsors non-qualified, non-contributory defined benefit pension plans that provide benefits to
certain key employees. Entergy recognized net periodic pension cost related to these plans of $32.4 million in 2014,
$54.5 million in 2013, and $26.5 million in 2012. In 2014, 2013, and 2012 Entergy recognized $15.1 million, $33
million, and $6.3 million, respectively in settlement charges related to the payment of lump sum benefits out of the
plan that is included in the non-qualified pension plan cost above. The projected benefit obligation was $151.8 million
and $154.3 million as of December 31, 2014 and 2013, respectively. The accumulated benefit obligation was $130.6
million and $131.4 million as of December 31, 2014 and 2013, respectively.
Entergy’s non-qualified, non-current pension liability at December 31, 2014 and 2013 was $135.6 million and
$127.5 million, respectively; and its current liability was $16.2 million and $26.8 million, respectively. The
unamortized prior service cost and net loss are recognized in regulatory assets ($60.3 million at December 31, 2014
and $59.1 million at December 31, 2013) and accumulated other comprehensive income before taxes ($23.5 million
at December 31, 2014 and $26.1 million at December 31, 2013).
The Registrant Subsidiaries (except System Energy) participate in Entergy’s non-qualified, non-contributory
defined benefit pension plans that provide benefits to certain key employees. The net periodic pension cost for their
employees for the non-qualified plans for 2014, 2013, and 2012, was as follows:
Entergy
Arkansas
2014
2013
2012
$754
$448
$464
Entergy
Gulf States
Louisiana
$130
$151
$158
Entergy
Entergy
Louisiana Mississippi
(In Thousands)
$5
$190
$12
$192
$12
$183
Entergy
New
Orleans
$95
$92
$79
Entergy
Texas
$491
$1,001
$648
Included in the 2014 net periodic pension cost above are settlement charges of $337 thousand and $16 thousand
for Entergy Arkansas and Entergy Texas, respectively, related to the lump sum benefits paid out of the plan. Included
in the 2013 net periodic pension cost above are settlement charges of $415 thousand for Entergy Texas related to the
lump sum benefits paid out of the plan. Included in the 2012 net periodic pension cost above are settlement charges
of $38 thousand for Entergy Arkansas related to the lump sum benefits paid out of the plan.
The projected benefit obligation for their employees for the non-qualified plans as of December 31, 2014 and
2013 was as follows:
Entergy
Arkansas
2014
2013
$4,495
$4,162
Entergy
Gulf States
Louisiana
$2,693
$2,511
Entergy
Entergy
Louisiana Mississippi
(In Thousands)
$158
$2,128
$50
$1,752
183
Entergy
New
Orleans
$476
$434
Entergy
Texas
$9,567
$7,910
E-5 Page 131 of 182
Entergy Corporation and Subsidiaries
Notes to Financial Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41
The accumulated benefit obligation for their employees for the non-qualified plans as of December 31, 2014
and 2013 was as follows:
Entergy
Arkansas
2014
2013
$4,086
$3,765
Entergy
Gulf States
Louisiana
$2,693
$2,510
Entergy
Entergy
Louisiana Mississippi
(In Thousands)
$131
$1,761
$50
$1,528
Entergy
New
Orleans
$436
$387
Entergy
Texas
$9,215
$7,496
The following amounts were recorded on the balance sheet as of December 31, 2014 and 2013:
2014
Current liabilities
Non-current liabilities
Total funded status
Regulatory asset/(liability)
Accumulated other
comprehensive income (before
taxes)
2013
Current liabilities
Non-current liabilities
Total funded status
Regulatory asset/(liability)
Accumulated other
comprehensive income (before
taxes)
Entergy
Arkansas
($347)
(4,148)
($4,495)
$2,368
$—
Entergy
Arkansas
($367)
(3,795)
($4,162)
$1,979
$—
Entergy
Gulf States
Louisiana
($241)
(2,452)
($2,693)
$659
Entergy
Louisiana
Entergy
Mississippi
(In Thousands)
($18)
($119)
(140)
(2,009)
($158)
($2,128)
$37
$942
$98
$—
$—
Entergy
Gulf States
Louisiana
Entergy
Louisiana
Entergy
Mississippi
($262)
(2,249)
($2,511)
$422
$57
184
(In Thousands)
($6)
($118)
(44)
(1,634)
($50)
($1,752)
($87)
$637
$—
$—
Entergy
New
Orleans
($23)
(453)
($476)
($65)
$—
Entergy
New
Orleans
($20)
(414)
($434)
($18)
$—
Entergy
Texas
($753)
(8,814)
($9,567)
$296
$—
Entergy
Texas
($786)
(7,124)
($7,910)
($1,631)
$—
E-5 Page 132 of 182
Entergy Corporation and Subsidiaries
Notes to Financial
Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc.
41
Reclassification out of Accumulated Other Comprehensive Income
Entergy and the Registrant Subsidiaries reclassified the following costs out of accumulated other
comprehensive income (before taxes and including amounts capitalized) as of December 31, 2014:
Qualified
Pension
Costs
Entergy
Amortization of prior service cost
Amortization of loss
Settlement loss
Entergy Gulf States Louisiana
Amortization of prior service cost
Amortization of loss
Entergy Louisiana
Amortization of prior service cost
Amortization of loss
Other
Postretirement Non-Qualified
Pension Costs
Costs
(In Thousands)
Total
($1,559)
(26,934)
—
($28,493)
$22,280
(6,689)
—
$15,591
($427)
(2,213)
(3,643)
($6,283)
$20,294
(35,836)
(3,643)
($19,185)
$—
(1,911)
($1,911)
$2,237
(1,212)
$1,025
$—
(3)
($3)
$2,237
(3,126)
($889)
$3,377
(1,511)
$1,866
$—
—
$—
$3,377
(1,511)
$1,866
$—
—
$—
185
E-5 Page 133 of 182
Entergy Corporation and Subsidiaries
Notes to Financial Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41
Entergy and the Registrant Subsidiaries reclassified the following costs out of accumulated other
comprehensive income (before taxes and including amounts capitalized) as of December 31, 2013:
Qualified
Pension
Costs
Entergy
Amortization of prior service cost
Acceleration of prior service cost due to
curtailment
Amortization of loss
Settlement loss
Entergy Gulf States Louisiana
Amortization of prior service cost
Acceleration of prior service cost due to
curtailment
Amortization of loss
Entergy Louisiana
Amortization of prior service cost
Acceleration of prior service cost due to
curtailment
Amortization of loss
Other
Postretirement Non-Qualified
Pension Costs
Costs
(In Thousands)
($1,866)
$12,925
(1,304)
(43,971)
—
($47,141)
1,797
(21,590)
—
($6,868)
($1)
—
(3,039)
($3,040)
$—
—
—
$—
$942
91
(4,598)
($3,565)
$508
41
(5,050)
($4,501)
($503)
(178)
(2,569)
(11,612)
($14,862)
$—
—
(7)
($7)
$—
—
—
$—
Total
$10,556
315
(68,130)
(11,612)
($68,871)
$941
91
(7,644)
($6,612)
$508
41
(5,050)
($4,501)
Accounting for Pension and Other Postretirement Benefits
Accounting standards require an employer to recognize in its balance sheet the funded status of its benefit
plans. This is measured as the difference between plan assets at fair value and the benefit obligation. Entergy uses a
December 31 measurement date for its pension and other postretirement plans. Employers are to record previously
unrecognized gains and losses, prior service costs, and any remaining transition asset or obligation (that resulted from
adopting prior pension and other postretirement benefits accounting standards) as comprehensive income and/or as a
regulatory asset reflective of the recovery mechanism for pension and other postretirement benefit costs in the Registrant
Subsidiaries’ respective regulatory jurisdictions. For the portion of Entergy Gulf States Louisiana that is not regulated,
the unrecognized prior service cost, gains and losses, and transition asset/obligation for its pension and other
postretirement benefit obligations are recorded as other comprehensive income. Entergy Gulf States Louisiana and
Entergy Louisiana recover other postretirement benefit costs on a pay-as-you-go basis and record the unrecognized
prior service cost, gains and losses, and transition obligation for its other postretirement benefit obligation as other
comprehensive income. Accounting standards also require that changes in the funded status be recorded as other
comprehensive income and/or a regulatory asset in the period in which the changes occur.
With regard to pension and other postretirement costs, Entergy calculates the expected return on pension and
other postretirement benefit plan assets by multiplying the long-term expected rate of return on assets by the marketrelated value (MRV) of plan assets. Entergy determines the MRV of pension plan assets by calculating a value that
uses a 20-quarter phase-in of the difference between actual and expected returns. For other postretirement benefit plan
assets Entergy uses fair value when determining MRV.
186
E-5 Page 134 of 182
Entergy Corporation and Subsidiaries
Notes to Financial
Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc.
41
Qualified Pension and Other Postretirement Plans’ Assets
The Plan Administrator’s trust asset investment strategy is to invest the assets in a manner whereby long-term
earnings on the assets (plus cash contributions) provide adequate funding for retiree benefit payments. The mix of
assets is based on an optimization study that identifies asset allocation targets in order to achieve the maximum return
for an acceptable level of risk, while minimizing the expected contributions and pension and postretirement expense.
In the optimization studies, the Plan Administrator formulates assumptions about characteristics, such as
expected asset class investment returns, volatility (risk), and correlation coefficients among the various asset classes.
The future market assumptions used in the optimization study are determined by examining historical market
characteristics of the various asset classes and making adjustments to reflect future conditions expected to prevail over
the study period.
The target asset allocation for pension adjusts dynamically based on the pension plans' funded status. The
current targets are shown below. The expectation is that the allocation to fixed income securities will increase as the
pension plans' funded status increases. The following ranges were established to produce an acceptable, economically
efficient plan to manage around the targets.
The target and range asset allocation for postretirement assets reflects changes made in 2012 as recommended
in the latest optimization study.
Entergy’s qualified pension and postretirement weighted-average asset allocations by asset category at
December 31, 2014 and 2013 and the target asset allocation and ranges are as follows:
Pension
Asset Allocation
Domestic Equity Securities
International Equity Securities
Fixed Income Securities
Other
Target
45%
20%
35%
0%
Postretirement
Asset Allocation
Range
34% to 53%
16% to 24%
31% to 41%
0% to 10%
Actual
2014
45%
19%
35%
1%
Actual
2013
46%
20%
33%
1%
Non-Taxable and Taxable
Target
Domestic Equity Securities
39%
International Equity Securities 26%
Fixed Income Securities
35%
Other
0%
Range
34% to 44%
21% to 31%
30% to 40%
0% to 5%
Actual Actual
2014 2013
42%
40%
25%
26%
33%
34%
0%
0%
In determining its expected long-term rate of return on plan assets used in the calculation of benefit plan costs,
Entergy reviews past performance, current and expected future asset allocations, and capital market assumptions of
its investment consultant and some investment managers.
The expected long-term rate of return for the qualified pension plans’ assets is based primarily on the geometric
average of the historical annual performance of a representative portfolio weighted by the target asset allocation defined
in the table above, along with other indications of expected return on assets. The time period reflected is a long dated
period spanning several decades.
187
E-5 Page 135 of 182
Entergy Corporation and Subsidiaries
Notes to Financial Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41
The expected long-term rate of return for the non-taxable postretirement trust assets is determined using the
same methodology described above for pension assets, but the asset allocation specific to the non-taxable postretirement
assets is used.
For the taxable postretirement trust assets, the investment allocation includes tax-exempt fixed income
securities. This asset allocation in combination with the same methodology employed to determine the expected return
for other trust assets (as described above), with a modification to reflect applicable taxes, is used to produce the expected
long-term rate of return for taxable postretirement trust assets.
Concentrations of Credit Risk
Entergy’s investment guidelines mandate the avoidance of risk concentrations. Types of concentrations
specified to be avoided include, but are not limited to, investment concentrations in a single entity, type of industry,
foreign country, geographic area and individual security issuance. As of December 31, 2014, all investment managers
and assets were materially in compliance with the approved investment guidelines, therefore there were no significant
concentrations (defined as greater than 10 percent of plan assets) of risk in Entergy’s pension and other postretirement
benefit plan assets.
Fair Value Measurements
Accounting standards provide the framework for measuring fair value. That framework provides a fair value
hierarchy that prioritizes the inputs to valuation techniques used to measure fair value. The hierarchy gives the highest
priority to unadjusted quoted prices in active markets for identical assets or liabilities (level 1 measurements) and the
lowest priority to unobservable inputs (level 3 measurements).
The three levels of the fair value hierarchy are described below:
•
Level 1 - Level 1 inputs are unadjusted quoted prices for identical assets or liabilities in active markets that
the Plan has the ability to access at the measurement date. Active markets are those in which transactions for
the asset or liability occur in sufficient frequency and volume to provide pricing information on an ongoing
basis.
•
Level 2 - Level 2 inputs are inputs other than quoted prices included in Level 1 that are, either directly or
indirectly, observable for the asset or liability at the measurement date. Assets are valued based on prices
derived by an independent party that uses inputs such as benchmark yields, reported trades, broker/dealer
quotes, and issuer spreads. Prices are reviewed and can be challenged with the independent parties and/or
overridden if it is believed such would be more reflective of fair value. Level 2 inputs include the following:
-
quoted prices for similar assets or liabilities in active markets;
quoted prices for identical assets or liabilities in inactive markets;
inputs other than quoted prices that are observable for the asset or liability; or
inputs that are derived principally from or corroborated by observable market data by correlation or other
means.
If an asset or liability has a specified (contractual) term, the Level 2 input must be observable for substantially
the full term of the asset or liability.
•
Level 3 - Level 3 refers to securities valued based on significant unobservable inputs.
Assets and liabilities are classified in their entirety based on the lowest level of input that is significant to the
fair value measurement. The following tables set forth by level within the fair value hierarchy, measured at fair value
188
E-5 Page 136 of 182
Entergy Corporation and Subsidiaries
Notes to Financial
Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc.
41
on a recurring basis at December 31, 2014, and December 31, 2013, a summary of the investments held in the master
trusts for Entergy’s qualified pension and other postretirement plans in which the Registrant Subsidiaries participate.
Qualified Defined Benefit Pension Plan Trusts
Final Average Pay Pension Plans’ Trust
2014
Equity securities:
Corporate stocks:
Preferred
Common
Common collective trusts
103-12 investment entities
Fixed income securities:
U.S. Government securities
Corporate debt instruments
Registered investment companies
Other
Other:
Insurance company general account
(unallocated contracts)
Total investments
Cash
Other pending transactions
Level 1
Level 2
Level 3
(In Thousands)
Total
$10,017 (b)
717,685 (b)
—
—
$— (a)
97
1,886,897 (c)
259,995 (h)
$—
—
—
—
$10,017
717,782
1,886,897
259,995
240 (b)
—
400,059 (a)
548,788 (a)
—
—
400,299
548,788
286,534 (d)
—
576,641 (e)
130,295 (f)
—
—
863,175
130,295
37,818 (g)
$3,840,590
—
$—
37,818
$4,855,066
314
7,359
—
$1,014,476
Less: Other postretirement assets
included in total investments
Total fair value of qualified
pension assets
(34,954)
$4,827,785
Cash Balance Pension Plans’ Trust
The Cash Balance pension plans’ trust held $181 thousand of cash as of December 31, 2014.
189
E-5 Page 137 of 182
Entergy Corporation and Subsidiaries
Notes to Financial Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41
2013
Equity securities:
Corporate stocks:
Preferred
Common
Common collective trusts
Fixed income securities:
U.S. Government securities
Corporate debt instruments
Registered investment companies
Other
Other:
Insurance company general account
(unallocated contracts)
Total investments
Cash
Other pending transactions
Less: Other postretirement
assets included in total investments
Total fair value of qualified
pension assets
Level 1
$6,847 (b)
915,996 (b)
—
180,718 (b)
—
316,863 (d)
—
—
$1,420,424
Level 2
Level 3
(In Thousands)
Total
$6,038 (a)
—
1,753,958 (c)
$—
—
—
$12,885
915,996
1,753,958
(a)
(a)
(e)
(f)
—
—
—
—
333,633
464,652
803,611
129,169
36,886 (g)
$3,030,366
—
$—
36,886
$4,450,790
280
8,081
152,915
464,652
486,748
129,169
(29,914)
$4,429,237
Other Postretirement Trusts
2014
Equity securities:
Common collective trust
Fixed income securities:
U.S. Government securities
Corporate debt instruments
Registered investment companies
Other
Total investments
Other pending transactions
Level 1
Level 2
Level 3
(In Thousands)
Total
$—
$370,228 (c)
$—
$370,228
36,306 (b)
—
5,558 (d)
—
$41,864
45,618 (a)
57,830 (a)
—
46,968 (f)
$520,644
—
—
—
—
$—
81,924
57,830
5,558
46,968
$562,508
165
Plus: Other postretirement assets included
in the investments of the qualified
pension trust
Total fair value of other
postretirement assets
34,954
$597,627
190
E-5 Page 138 of 182
Entergy Corporation and Subsidiaries
Notes to Financial
Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc.
41
2013
Equity securities:
Common collective trust
Fixed income securities:
U.S. Government securities
Corporate debt instruments
Registered investment
companies
Other
Total investments
Other pending transactions
Plus: Other postretirement assets included
in the investments of the qualified
pension trust
Total fair value of other
postretirement assets
(a)
(b)
(c)
(d)
(e)
(f)
(g)
(h)
Level 1
Level 2
Level 3
(In Thousands)
$—
Total
$356,700 (c)
$—
$356,700
40,808 (b)
—
43,471 (a)
50,563 (a)
—
—
84,279
50,563
4,163 (d)
—
$44,971
—
43,458 (f)
$494,192
—
—
$—
4,163
43,458
$539,163
773
29,914
$569,850
Certain preferred stocks and certain fixed income debt securities (corporate, government, and securitized) are
stated at fair value as determined by broker quotes.
Common stocks, certain preferred stocks, and certain fixed income debt securities (government) are stated at
fair value determined by quoted market prices.
The common collective trusts hold investments in accordance with stated objectives. The investment strategy
of the trusts is to capture the growth potential of equity markets by replicating the performance of a specified
index. Net asset value per share of the common collective trusts estimate fair value.
The registered investment company is a money market mutual fund with a stable net asset value of one dollar
per share.
The registered investment company holds investments in domestic and international bond markets and estimates
fair value using net asset value per share.
The other remaining assets are U.S. municipal and foreign government bonds stated at fair value as determined
by broker quotes.
The unallocated insurance contract investments are recorded at contract value, which approximates fair
value. The contract value represents contributions made under the contract, plus interest, less funds used to
pay benefits and contract expenses, and less distributions to the master trust.
103-12 investment entities hold investments in accordance with stated objectives. The investment strategy of
the investment entities is to capture the growth potential of international equity markets by replicating the
performance of a specified index. Net asset value per share of the 103-12 investment entities estimate fair
value.
Accumulated Pension Benefit Obligation
The accumulated benefit obligation for Entergy’s qualified pension plans was $6.6 billion and $5.2 billion at
December 31, 2014 and 2013, respectively.
191
E-5 Page 139 of 182
Entergy Corporation and Subsidiaries
Notes to Financial Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41
The qualified pension accumulated benefit obligation for each of the Registrant Subsidiaries for their employees
as of December 31, 2014 and 2013 was as follows:
December 31,
2014
2013
(In Thousands)
$1,379,108
$1,107,023
$649,932
$530,974
$873,759
$697,945
$399,300
$318,941
$186,473
$150,239
$391,296
$332,484
$305,556
$247,807
Entergy Arkansas
Entergy Gulf States Louisiana
Entergy Louisiana
Entergy Mississippi
Entergy New Orleans
Entergy Texas
System Energy
Estimated Future Benefit Payments
Based upon the assumptions used to measure Entergy’s qualified pension and other postretirement benefit
obligations at December 31, 2014, and including pension and other postretirement benefits attributable to estimated
future employee service, Entergy expects that benefits to be paid and the Medicare Part D subsidies to be received
over the next ten years for Entergy Corporation and its subsidiaries will be as follows:
Estimated Future Benefits Payments
Other
Postretirement
Non(before
Qualified
Qualified
Medicare
Pension
Pension
Subsidy)
(In Thousands)
Year(s)
2015
2016
2017
2018
2019
2020 - 2024
$262,792
$277,307
$292,841
$310,200
$328,533
$1,966,776
$16,173
$9,976
$10,774
$12,598
$11,431
$70,791
$78,601
$80,601
$83,425
$88,049
$92,253
$506,086
Estimated
Future
Medicare
Subsidy
Receipts
$455
$525
$595
$1,785
$1,984
$13,539
Based upon the same assumptions, Entergy expects that benefits to be paid and the Medicare Part D subsidies
to be received over the next ten years for the Registrant Subsidiaries for their employees will be as follows:
Estimated Future
Qualified Pension
Benefits Payments
Entergy
Arkansas
Entergy
Gulf States
Louisiana
Entergy
Louisiana
Entergy
Mississippi
Entergy
New Orleans
Entergy
Texas
System
Energy
(In Thousands)
Year(s)
2015
2016
2017
2018
2019
2020 - 2024
$66,156
$67,639
$69,207
$71,306
$73,795
$418,009
$25,450
$26,805
$28,340
$30,279
$32,445
$196,323
$37,892
$39,070
$40,675
$42,336
$44,058
$256,639
192
$18,702
$19,625
$20,517
$21,444
$22,306
$125,761
$7,397
$7,836
$8,304
$8,895
$9,368
$56,659
$19,078
$19,697
$20,558
$21,448
$22,291
$125,001
$11,432
$11,949
$12,357
$12,977
$13,724
$87,663
E-5 Page 140 of 182
Entergy Corporation and Subsidiaries
Notes to Financial
Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc.
41
Estimated Future
Non-Qualified
Pension Benefits
Payments
Entergy
Arkansas
Entergy
Gulf States
Louisiana
Entergy
Louisiana
Entergy
Mississippi
Entergy
New Orleans
Entergy
Texas
(In Thousands)
Year(s)
2015
2016
2017
2018
2019
2020 - 2024
Estimated Future
Other
Postretirement
Benefits Payments
(before Medicare
Part D Subsidy)
$347
$300
$291
$282
$339
$2,684
Entergy
Arkansas
Entergy
Gulf States
Louisiana
$241
$228
$241
$205
$199
$924
$18
$17
$16
$15
$17
$90
Entergy
Louisiana
$119
$115
$124
$114
$112
$825
Entergy
Mississippi
$23
$23
$23
$23
$46
$199
Entergy
New Orleans
$753
$837
$784
$749
$720
$3,442
Entergy
Texas
System
Energy
(In Thousands)
Year(s)
2015
2016
2017
2018
2019
2020 - 2024
Estimated
Future
Medicare Part D
Subsidy
Year(s)
2015
2016
2017
2018
2019
2020 - 2024
$15,699
$15,745
$15,830
$16,305
$16,528
$86,854
$8,921
$9,219
$9,580
$10,110
$10,706
$59,199
$9,885
$10,016
$10,148
$10,654
$11,048
$60,735
Entergy
Arkansas
Entergy
Gulf
States
Louisiana
Entergy
Louisiana
$77
$87
$96
$358
$398
$2,593
$37
$41
$46
$168
$184
$1,243
$45
$50
$56
$204
$223
$1,434
$3,926
$4,001
$4,125
$4,433
$4,599
$25,341
$4,261
$4,253
$4,280
$4,373
$4,412
$21,584
Entergy
Entergy
Mississippi New Orleans
(In Thousands)
$29
$32
$34
$125
$136
$839
$23
$24
$25
$87
$90
$506
$6,617
$6,785
$7,012
$7,438
$7,771
$41,303
$2,796
$2,802
$2,883
$2,984
$3,138
$17,664
Entergy
Texas
System
Energy
$34
$37
$40
$142
$151
$922
$9
$11
$1
$52
$59
$456
Contributions
Entergy currently expects to contribute approximately $396 million to its qualified pension plans and
approximately $66.9 million to other postretirement plans in 2015. The expected 2015 pension and other postretirement
plan contributions of the Registrant Subsidiaries for their employees are shown below. The required pension
contributions will not be known with more certainty until the January 1, 2015 valuations are completed by April 1,
2015.
193
E-5 Page 141 of 182
Entergy Corporation and Subsidiaries
Notes to Financial Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41
The Registrant Subsidiaries expect to contribute approximately the following to the qualified pension and other
postretirement plans for their employees in 2015:
Entergy
Arkansas
Entergy
Gulf States
Louisiana
Entergy
Louisiana
Entergy
New
Orleans
Entergy
Mississippi
Entergy
Texas
System
Energy
(In Thousands)
Pension
Contributions
Other
Postretirement
Contributions
$92,523
$32,455
$56,960
$22,472
$10,910
$17,166
$20,778
$16,904
$8,921
$9,885
$535
$3,669
$3,231
$475
Actuarial Assumptions
The significant actuarial assumptions used in determining the pension PBO and the other postretirement benefit
APBO as of December 31, 2014, and 2013 were as follows:
Weighted-average discount rate:
Qualified pension
Other postretirement
Non-qualified pension
Weighted-average rate of increase in future compensation levels
Assumed health care trend rate:
Pre-65
Post-65
Ultimate rate
Year ultimate rate is reached and beyond:
Pre-65
Post-65
194
2014
2013
4.03% - 4.40%
Blended 4.27%
4.23%
3.61%
5.04% - 5.26%
Blended 5.14%
5.05%
4.29%
4.23%
4.23%
7.10%
7.70%
4.75%
7.25%
7.00%
4.75%
2023
2023
2022
2022
E-5 Page 142 of 182
Entergy Corporation and Subsidiaries
Notes to Financial
Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc.
41
The significant actuarial assumptions used in determining the net periodic pension and other postretirement
benefit costs for 2014, 2013, and 2012 were as follows:
Weighted-average discount rate:
Qualified pension
2014
2013
2012
5.04%-5.26%
Blended 5.14%
4.31% - 4.5%
Blended 4.36%
5.10% - 5.20%
Blended 5.11%
5.05%
4.29%
4.36%
3.37%
5.10%
4.40%
4.23%
4.23%
4.23%
8.50%
8.30%
6.50%
8.50%
8.50%
6.50%
8.50%
8.50%
6.50%
7.25%
7.00%
4.75%
7.50%
7.25%
4.75%
7.75%
7.50%
4.75%
2022
2022
2022
2022
2022
2022
Other postretirement
Non-qualified pension
Weighted-average rate of increase
in future compensation levels
Expected long-term rate of
return on plan assets:
Pension assets
Other postretirement tax deferred assets
Other postretirement taxable assets
Assumed health care trend rate:
Pre-65
Post-65
Ultimate rate
Year ultimate rate is reached and
beyond:
Pre-65
Post-65
Entergy’s other postretirement benefit transition obligations were amortized over 20 years ending in 2012.
With respect to mortality assumptions, Entergy used the RP-2014 Employee and Health Annuitant Tables, with
a fully generational MP-2014 projection scale, in determining its December 31, 2014 pension plans’ PBOs and other
postretirement benefit APBO. The mortality assumptions used in determining Entergy’s December 31, 2013 pension
plans’ PBOs were the 1994 Group Annuity Mortality Table and RP 2000 Combined Health Mortality, with generational
(using Scale AA) projected mortality improvement. The mortality assumption used in determining the December 31,
2013 other postretirement APBO was the 1994 Group Annuity Mortality Table, with generational (using Scale AA)
projected mortality improvement.
A one percentage point change in the assumed health care cost trend rate for 2014 would have the following
effects:
1 Percentage Point Increase
2014
Entergy Corporation and its
subsidiaries
Impact on the
APBO
1 Percentage Point Decrease
Impact on the
sum of service
costs and
Impact on the
interest cost
APBO
Increase /(Decrease)
(In Thousands)
$234,971
$16,769
195
($190,996)
Impact on the
sum of service
costs and
interest cost
($13,566)
E-5 Page 143 of 182
Entergy Corporation and Subsidiaries
Notes to Financial Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41
A one percentage point change in the assumed health care cost trend rate for 2014 would have the following
effects for the Registrant Subsidiaries for their employees:
2014
Entergy Arkansas
Entergy Gulf States Louisiana
Entergy Louisiana
Entergy Mississippi
Entergy New Orleans
Entergy Texas
System Energy
1 Percentage Point Increase
1 Percentage Point Decrease
Impact on the
Impact on the
sum of service
sum of service
Impact on the
costs and
Impact on the
costs and
APBO
interest cost
APBO
interest cost
Increase/(Decrease)
(In Thousands)
$39,286
$2,448
($31,753)
($1,971)
$27,929
$2,092
($22,591)
($1,671)
$23,779
$1,681
($19,452)
($1,366)
$10,596
$754
($8,596)
($606)
$6,373
$386
($5,317)
($321)
$16,246
$1,148
($13,397)
($927)
$8,716
$734
($7,044)
($586)
Defined Contribution Plans
Entergy sponsors the Savings Plan of Entergy Corporation and Subsidiaries (System Savings Plan). The
System Savings Plan is a defined contribution plan covering eligible employees of Entergy and certain of its subsidiaries.
The participating employing Entergy subsidiary makes matching contributions to the System Savings Plan for all
eligible participating employees in an amount equal to either 70% or 100% of the participants’ basic contributions, up
to 6% of their eligible earnings per pay period. The matching contribution is allocated to investments as directed by
the employee.
Entergy also sponsors the Savings Plan of Entergy Corporation and Subsidiaries IV (established in March
2002), the Savings Plan of Entergy Corporation and Subsidiaries VI (established in April 2007), and the Savings Plan
of Entergy Corporation and Subsidiaries VII (established in April 2007) to which matching contributions are also
made. The plans are defined contribution plans that cover eligible employees, as defined by each plan, of Entergy and
certain of its subsidiaries.
Entergy’s subsidiaries’ contributions to defined contribution plans collectively were $43.3 million in 2014,
$44.5 million in 2013, and $43.7 million in 2012. The majority of the contributions were to the System Savings Plan.
The Registrant Subsidiaries’ 2014, 2013, and 2012 contributions to defined contribution plans for their
employees were as follows:
Year
2014
2013
2012
NOTE 12.
Entergy
Arkansas
$3,044
$3,351
$3,223
Entergy
Gulf States
Louisiana
$1,867
$1,906
$1,842
Entergy
Louisiana
Entergy
Mississippi
Entergy
New Orleans
(In Thousands)
$2,266
$1,855
$2,393
$1,954
$2,327
$1,875
$710
$769
$740
Entergy
Texas
$1,563
$1,616
$1,601
STOCK-BASED COMPENSATION (Entergy Corporation)
Entergy grants stock options, restricted stock, performance units, and restricted unit awards to key employees
of the Entergy subsidiaries under its Equity Ownership Plans which are shareholder-approved stock-based compensation
196
E-5 Page 144 of 182
Entergy Corporation and Subsidiaries
Notes to Financial
Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc.
41
plans. The Equity Ownership Plan, as restated in February 2003 (2003 Plan), had 885,200 authorized shares remaining
for long-term incentive and restricted unit awards as of December 31, 2014. Effective January 1, 2007, Entergy’s
shareholders approved the 2007 Equity Ownership and Long-Term Cash Incentive Plan (2007 Plan). The maximum
aggregate number of common shares that can be issued from the 2007 Plan for stock-based awards is 7,000,000 with
no more than 2,000,000 available for non-option grants. The 2007 Plan, which only applies to awards made on or after
January 1, 2007, will expire after 10 years. As of December 31, 2014, there were 1,104,547 authorized shares remaining
for stock-based awards, all of which are available for non-option grants. Effective May 6, 2011, Entergy’s shareholders
approved the 2011 Equity Ownership and Long-Term Cash Incentive Plan (2011 Plan). The maximum number of
common shares that can be issued from the 2011 Plan for stock-based awards is 5,500,000 with no more than 2,000,000
available for incentive stock option grants. The 2011 Plan, which only applies to awards made on or after May 6, 2011,
will expire after 10 years. As of December 31, 2014, there were 1,579,563 authorized shares remaining for stockbased awards, including 2,000,000 for incentive stock option grants.
Stock Options
Stock options are granted at exercise prices that equal the closing market price of Entergy Corporation common
stock on the date of grant. Generally, stock options granted will become exercisable in equal amounts on each of the
first three anniversaries of the date of grant. Unless they are forfeited previously under the terms of the grant, options
expire ten years after the date of the grant if they are not exercised.
The following table includes financial information for stock options for each of the years presented:
2014
Compensation expense included in Entergy’s Consolidated Net Income
Tax benefit recognized in Entergy’s Consolidated Net Income
Compensation cost capitalized as part of fixed assets and inventory
2013
(In Millions)
$4.1
$4.1
$1.6
$1.6
$0.7
$0.7
2012
$7.7
$3.0
$1.5
Entergy determines the fair value of the stock option grants by considering factors such as lack of marketability,
stock retention requirements, and regulatory restrictions on exercisability in accordance with accounting standards. The
stock option weighted-average assumptions used in determining the fair values are as follows:
Stock price volatility
Expected term in years
Risk-free interest rate
Dividend yield
Dividend payment per share
2014
24.67%
6.95
2.16%
4.75%
$3.32
2013
24.61%
6.69
1.31%
4.75%
$3.32
2012
25.11%
6.55
1.22%
4.50%
$3.32
Stock price volatility is calculated based upon the daily public stock price volatility of Entergy Corporation common
stock over a period equal to the expected term of the award. The expected term of the options is based upon historical
option exercises and the weighted average life of options when exercised and the estimated weighted average life of
all vested but unexercised options. In 2008, Entergy implemented stock ownership guidelines for its senior executive
officers. These guidelines require an executive officer to own shares of Entergy Corporation common stock equal to
a specified multiple of his or her salary. Until an executive officer achieves this ownership position the executive
officer is required to retain 75% of the after-tax net profit upon exercise of the option to be held in Entergy Corporation
common stock. The reduction in fair value of the stock options due to this restriction is based upon an estimate of the
call option value of the reinvested gain discounted to present value over the applicable reinvestment period.
197
E-5 Page 145 of 182
Entergy Corporation and Subsidiaries
Notes to Financial Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41
A summary of stock option activity for the year ended December 31, 2014 and changes during the year are
presented below:
Number
of Options
9,639,849
611,700
(2,852,350)
(117,803)
7,281,396
6,232,998
Options outstanding as of January 1, 2014
Options granted
Options exercised
Options forfeited/expired
Options outstanding as of December 31, 2014
Options exercisable as of December 31, 2014
Weighted-average grant-date fair value of
options granted during 2014
WeightedAverage
Exercise
Price
$80.06
$63.17
$68.19
$82.48
$83.25
$86.41
Aggregate
Intrinsic
Value
WeightedAverage
Contractual
Life
$30,830,809
$6,657,504
4.3 years
3.6 years
$8.71
The weighted-average grant-date fair value of options granted during the year was $8.00 for 2013 and $9.42 for
2012. The total intrinsic value of stock options exercised was $25.5 million during 2014, $5.7 million during 2013,
and $39.8 million during 2012. The intrinsic value, which has no effect on net income, of the stock options exercised
is calculated by the difference in Entergy Corporation’s common stock price on the date of exercise and the exercise
price of the stock options granted. The aggregate intrinsic value of the stock options outstanding as of December 31,
2014 was $30.8 million. Entergy recognizes compensation cost over the vesting period of the options based on their
grant-date fair value. The total fair value of options that vested was approximately $4 million during 2014, $11 million
during 2013, and $11 million during 2012.
The following table summarizes information about stock options outstanding as of December 31, 2014:
Options Outstanding
Range of
Exercise Prices
$51 - $64.99
$65 - $78.99
$79 - $91.99
$92 - $108.20
$51 - $108.20
As of
12/31/2014
1,138,602
3,095,377
1,604,717
1,442,700
7,281,396
WeightedAvg.
Remaining
Contractual
Life-Yrs.
8.6
4.4
2.1
3.1
4.3
Weighted
Avg.
Exercise
Price
$63.84
$74.31
$91.82
$108.20
$83.25
Options Exercisable
Number
Exercisable
as of
12/31/2014
192,152
2,993,429
1,604,717
1,442,700
6,232,998
Weighted
Avg.
Exercise
Price
$64.60
$74.41
$91.82
$108.20
$86.41
Stock-based compensation cost related to non-vested stock options outstanding as of December 31, 2014 not
yet recognized is approximately $5.4 million and is expected to be recognized over a weighted-average period of 1.7
years.
Restricted Stock Awards
In January 2014 the Board approved and Entergy granted 352,600 restricted stock awards under the 2011
Equity Ownership and Long-term Cash Incentive Plan. The restricted stock awards were made effective as of January
30, 2014 and were valued at $63.17 per share, which was the closing price of Entergy Corporation’s common stock
on that date. One-third of the restricted stock awards will vest upon each anniversary of the grant date and are expensed
198
E-5 Page 146 of 182
Entergy Corporation and Subsidiaries
Notes to Financial
Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc.
41
ratably over the three year vesting period. Shares of restricted stock have the same dividend and voting rights as other
common stock and are considered issued and outstanding shares of Entergy upon vesting.
The following table includes financial information for restricted stock for each of the years presented:
2014
Compensation expense included in Entergy’s Consolidated Net Income
Tax benefit recognized in Entergy’s Consolidated Net Income
Compensation cost capitalized as part of fixed assets and inventory
2013
(In Millions)
$19.3
$16.4
$7.5
$6.3
$3.1
$2.6
2012
$11.4
$4.4
$2.0
Long-Term Performance Unit Program
Entergy grants long-term incentive awards earned under its stock benefit plans in the form of performance
units, which are equal to the cash value of shares of Entergy Corporation common stock at the end of the performance
period, which is the last trading day of the year. Performance units will pay out to the extent that the performance
conditions are satisfied. In addition to the potential for equivalent share appreciation or depreciation, performance
units will earn the cash equivalent of the dividends paid during the 3-year performance period applicable to each
plan. The costs of incentive awards are charged to income over the 3-year period. Beginning with the 2012-2014
performance period, upon vesting, the performance units granted under the Long-Term Performance Unit Program
will be settled in shares of Entergy common stock rather than cash. In January 2014 the Board approved and Entergy
granted 226,792 performance units under the 2011 Equity Ownership and Long-Term Cash Incentive Plan. The
performance units were made effective as of January 30, 2014, and were valued at $67.16 per share. Entergy considers
factors, primarily market conditions, in determining the value of the performance units. Shares of the performance
units have the same dividend and voting rights as other common stock, are considered issued and outstanding shares
of Entergy upon vesting, and are expensed ratably over the 3-year vesting period.
The following table includes financial information for the long-term performance units for each of the years
presented:
2014
Fair value of long-term performance units as of December 31,
Compensation expense included in Entergy’s Consolidated Net Income
Tax benefit (expense) recognized in Entergy’s Consolidated Net Income
Compensation cost capitalized as part of fixed assets and inventory
$23.4
$10.7
$4.1
$1.5
2013
(In Millions)
$11.1
$6.0
$2.3
$0.9
2012
$4.3
($5.0)
($1.9)
($0.9)
There was no payout in 2014 for the performance units granted in 2011 applicable to the 2011 – 2013 performance
period.
Restricted Unit Awards
Entergy grants restricted unit awards earned under its stock benefit plans in the form of stock units that are
subject to time-based restrictions. The restricted units are equal to the cash value of shares of Entergy Corporation
common stock at the time of vesting. The costs of restricted unit awards are charged to income over the restricted
period, which varies from grant to grant. The average vesting period for restricted unit awards granted is 36 months. As
of December 31, 2014, there were 98,334 unvested restricted units that are expected to vest over an average period of
21 months.
199
E-5 Page 147 of 182
Entergy Corporation and Subsidiaries
Notes to Financial Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41
The following table includes financial information for restricted unit awards for each of the years presented:
2014
Fair value of restricted awards as of December 31,
Compensation expense included in Entergy’s Consolidated Net Income
Tax benefit recognized in Entergy’s Consolidated Net Income
Compensation cost capitalized as part of fixed assets and inventory
$3.3
$2.2
$0.9
$0.3
2013
(In Millions)
$2.5
$1.4
$0.6
$0.2
2012
$3.0
$1.3
$0.5
$0.2
Entergy paid $1.7 million in 2014 for awards under the Restricted Units Awards Plan.
NOTE 13. BUSINESS SEGMENT INFORMATION (Entergy Corporation, Entergy Arkansas, Entergy Gulf
States Louisiana, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System
Energy)
Entergy’s reportable segments as of December 31, 2014 are Utility and Entergy Wholesale
Commodities. Utility includes the generation, transmission, distribution, and sale of electric power in portions of
Arkansas, Louisiana, Mississippi, and Texas, and natural gas utility service in portions of Louisiana. Entergy Wholesale
Commodities includes the ownership, operation, and decommissioning of nuclear power plants located in the northern
United States and the sale of the electric power produced by its operating plants to wholesale customers. Entergy
Wholesale Commodities also includes the ownership of interests in non-nuclear power plants that sell the electric
power produced by those plants to wholesale customers. “All Other” includes the parent company, Entergy Corporation,
and other business activity.
Entergy’s segment financial information is as follows:
2014
Operating revenues
Depreciation, amortization, &
decommissioning
Interest and investment income
Interest expense
Income taxes
Consolidated net income (loss)
Total assets
Investment in affiliates - at equity
Cash paid for long-lived asset
additions
Utility
$9,773,822
Entergy
Wholesale
Commodities*
All Other Eliminations Consolidated
(In Thousands)
$2,719,404
$1,821
($126)
$12,494,921
$1,170,122
$171,217
$531,729
$472,148
$846,496
$38,295,309
$199
$417,435
$113,959
$16,646
$176,988
$294,521
$10,279,500
$36,035
$2,113,631
$615,021
200
$3,702
$22,159
$120,908
($59,539)
($62,887)
($654,831)
$—
$87
$—
($159,649)
($41,776)
$—
($117,873)
($1,392,124)
$—
$—
$1,591,259
$147,686
$627,507
$589,597
$960,257
$46,527,854
$36,234
$2,728,739
E-5 Page 148 of 182
Entergy Corporation and Subsidiaries
Notes to Financial
Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc.
41
2013
Operating revenues
Depreciation, amortization, &
decommissioning
Interest and investment income
Interest expense
Income taxes
Consolidated net income (loss)
Total assets
Investment in affiliates - at equity
Cash paid for long-lived asset
additions
2012
Operating revenues
Depreciation, amortization, &
decommissioning
Interest and investment income
Interest expense
Income taxes
Consolidated net income (loss)
Total assets
Investment in affiliates - at equity
Cash paid for long-lived asset
additions
Utility
$9,101,786
Entergy
Wholesale
Commodities* All Other Eliminations Consolidated
(In Thousands)
$2,312,758
$3,558
($27,155)
$11,390,947
$1,157,843
$186,724
$509,173
$365,917
$846,215
$35,539,585
$199
$341,163
$137,727
$16,323
($77,471)
$42,976
$9,696,705
$40,151
$2,268,083
$626,322
Utility
$8,005,091
$4,142
$24,179
$122,291
($62,465)
($53,039)
($486,438)
$—
$49
$—
($149,330)
($43,750)
$—
($105,580)
($1,343,406)
$—
$—
$1,503,148
$199,300
$604,037
$225,981
$730,572
$43,406,446
$40,350
$2,894,454
Entergy
Wholesale
Commodities*
All Other Eliminations Consolidated
(In Thousands)
$2,326,309
$4,048
($33,369)
$10,302,079
$1,076,845
$150,292
$476,485
$49,340
$960,322
$35,438,130
$199
$248,143
$105,062
$17,900
$61,329
$40,427
$9,623,345
$46,539
$3,182,695
$577,652
$4,357
$30,656
$126,913
($79,814)
($26,167)
($509,985)
$—
$619
$—
($158,234)
($52,014)
$—
($106,219)
($1,348,988)
$—
$—
$1,329,345
$127,776
$569,284
$30,855
$868,363
$43,202,502
$46,738
$3,760,966
Businesses marked with * are sometimes referred to as the “competitive businesses.” Eliminations are primarily
intersegment activity. Almost all of Entergy’s goodwill is related to the Utility segment.
Earnings were negatively affected by expenses in 2013 of approximately $110 million ($70 million after-tax),
including approximately $85 million ($55 million after-tax) for Utility and $25 million ($15 million after-tax) for
Entergy Wholesale Commodities, and expenses in 2014 of approximately $20 million ($12 million after-tax), including
approximately $15 million ($9 million after-tax) for Utility and $5 million ($3 million after-tax) for Entergy Wholesale
Commodities, recorded in connection with a strategic imperative intended to optimize the organization through a
process known as human capital management. In July 2013 management completed a comprehensive review of
Entergy’s organization design and processes. This effort resulted in a new internal organization structure, which resulted
in the elimination of approximately 800 employee positions. The restructuring costs associated with this phase of
human capital management included implementation costs, severance expenses, benefits-related costs, including
pension curtailment losses and special termination benefits, and impairments of corporate property, plant, and
equipment. The implementation costs, severance costs, and benefits-related costs are included in “Other operation
and maintenance” in the consolidated income statements. The property, plant, and equipment impairments are included
in “Asset write-offs, impairments, and related charges” in the consolidated income statements. Total restructuring
charges were comprised of the following:
201
E-5 Page 149 of 182
Entergy Corporation and Subsidiaries
Notes to Financial Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41
2013
Paid
Restructuring
In
Costs
Cash
Implementation costs
Severance costs
Benefits-related costs
Property, plant, and
equipment
impairments
Total
$19
45
26
$19
6
—
20
$110
—
$25
2014
NonPaid
Cash
Restructuring
In
Portion
Costs
Cash
(In Millions)
$—
$9
$9
—
11
44
26
—
—
20
$46
—
$20
NonCash
Portion
Remaining
Accrual as of
December 31,
2014
$—
—
—
$—
6
—
—
$—
—
$6
—
$53
Geographic Areas
For the years ended December 31, 2014, 2013, and 2012, the amount of revenue Entergy derived from outside
of the United States was insignificant. As of December 31, 2014 and 2013, Entergy had no long-lived assets located
outside of the United States.
Registrant Subsidiaries
Each of the Registrant Subsidiaries has one reportable segment, which is an integrated utility business, except
for System Energy, which is an electricity generation business. Each of the Registrant Subsidiaries’ operations is
managed on an integrated basis by that company because of the substantial effect of cost-based rates and regulatory
oversight on the business process, cost structures, and operating results.
NOTE 14. EQUITY METHOD INVESTMENTS (Entergy Corporation)
As of December 31, 2014, Entergy owns investments in the following companies that it accounts for under
the equity method of accounting:
Investment
Ownership
Description
RS Cogen LLC
50% member
interest
Co-generation project that produces power and steam on an
industrial and merchant basis in the Lake Charles, Louisiana area.
Top Deer
50% member
interest
Wind-powered electric generation joint venture.
Following is a reconciliation of Entergy’s investments in equity affiliates:
2014
Beginning of year
Income (loss) from the investments
Dispositions and other adjustments
End of year
$40,350
(5,169)
1,053
$36,234
202
2013
(In Thousands)
$46,738
(1,702)
(4,686)
$40,350
2012
$44,876
1,162
700
$46,738
E-5 Page 150 of 182
Entergy Corporation and Subsidiaries
Notes to Financial
Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc.
41
Transactions with equity method investees
Entergy Gulf States Louisiana purchased approximately $3.2 million in 2013 and $2.8 million in 2012 of
electricity generated from Entergy’s share of RS Cogen. Entergy Gulf States Louisiana made no purchases in 2014
of electricity generated from Entergy’s share of RS Cogen. Entergy’s operating transactions with its other equity
method investees were not significant in 2014, 2013, or 2012.
NOTE 15. ACQUISITIONS AND DISPOSITIONS (Entergy Corporation, Entergy Arkansas, Entergy
Louisiana, and Entergy Mississippi)
Acquisitions
Hot Spring Energy Facility
In November 2012, Entergy Arkansas purchased the Hot Spring Energy Facility, a 620 MW combined-cycle
natural gas turbine unit located in Malvern, Arkansas, from KGen Hot Spring LLC for approximately $253 million. The
FERC and the APSC approved the transaction.
Hinds Energy Facility
In November 2012, Entergy Mississippi purchased the Hinds Energy Facility, a 450 MW combined-cycle
natural gas turbine unit located in Jackson, Mississippi, from KGen Hinds LLC for approximately $206 million. The
FERC and the MPSC approved the transaction.
Palisades Purchased Power Agreement
Entergy’s purchase of the Palisades plant in 2007 included a unit-contingent, 15-year purchased power
agreement (PPA) with Consumers Energy for 100% of the plant’s output, excluding any future uprates. Prices under
the PPA range from $43.50/MWh in 2007 to $61.50/MWh in 2022, and the average price under the PPA is $51/
MWh. For the PPA, which was at below-market prices at the time of the acquisition, Entergy will amortize a liability
to revenue over the life of the agreement. The amount that will be amortized each period is based upon the difference
between the present value calculated at the date of acquisition of each year’s difference between revenue under the
agreement and revenue based on estimated market prices. Amounts amortized to revenue were $16 million in 2014,
$18 million in 2013, and $17 million in 2012. The amounts to be amortized to revenue for the next five years will be
$15 million in 2015, $13 million for 2016, $12 million for 2017, $8 million for 2018, and $13 million for 2019.
NYPA Value Sharing Agreements
Entergy’s purchase of the FitzPatrick and Indian Point 3 plants from NYPA included value sharing agreements
with NYPA. In October 2007, Entergy subsidiaries and NYPA amended and restated the value sharing agreements to
clarify and amend certain provisions of the original terms. Under the amended value sharing agreements, Entergy
subsidiaries made annual payments to NYPA based on the generation output of the Indian Point 3 and FitzPatrick plants
from January 2007 through December 2014. Entergy subsidiaries paid NYPA $6.59 per MWh for power sold from
Indian Point 3, up to an annual cap of $48 million, and $3.91 per MWh for power sold from FitzPatrick, up to an annual
cap of $24 million. The annual payment for each year’s output was due by January 15 of the following year. Entergy
recorded the liability for payments to NYPA as power is generated and sold by Indian Point 3 and FitzPatrick. An
amount equal to the liability was recorded to the plant asset account as contingent purchase price consideration for the
plants. In 2014, 2013, and 2012, Entergy Wholesale Commodities recorded approximately $72 million as plant for
generation during each of those years. This amount was depreciated over the expected remaining useful life of the
plants.
203
E-5 Page 151 of 182
Entergy Corporation and Subsidiaries
Notes to Financial Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41
Dispositions
In November 2013, Entergy sold Entergy Solutions District Energy, a business wholly-owned by Entergy in
the Entergy Wholesale Commodities segment that owns and operates district energy assets serving the business districts
in Houston and New Orleans. Entergy sold Entergy Solutions District Energy for $140 million and realized a pre-tax
gain of $44 million on the sale.
NOTE 16. RISK MANAGEMENT AND FAIR VALUES (Entergy Corporation, Entergy Arkansas, Entergy
Gulf States Louisiana, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and
System Energy)
Market Risk
In the normal course of business, Entergy is exposed to a number of market risks. Market risk is the potential
loss that Entergy may incur as a result of changes in the market or fair value of a particular commodity or instrument. All
financial and commodity-related instruments, including derivatives, are subject to market risk including commodity
price risk, equity price, and interest rate risk. Entergy uses derivatives primarily to mitigate commodity price risk,
particularly power price and fuel price risk.
The Utility has limited exposure to the effects of market risk because it operates primarily under cost-based
rate regulation. To the extent approved by their retail regulators, the Utility operating companies use derivative
instruments to hedge the exposure to price volatility inherent in their purchased power, fuel, and gas purchased for
resale costs that are recovered from customers.
As a wholesale generator, Entergy Wholesale Commodities’ core business is selling energy, measured in MWh,
to its customers. Entergy Wholesale Commodities enters into forward contracts with its customers and also sells energy
and capacity in the day ahead or spot markets. In addition to its forward physical power contracts, Entergy Wholesale
Commodities also uses a combination of financial contracts, including swaps, collars, and options, to mitigate
commodity price risk. When the market price falls, the combination of instruments is expected to settle in gains that
offset lower revenue from generation, which results in a more predictable cash flow.
Entergy’s exposure to market risk is determined by a number of factors, including the size, term, composition,
and diversification of positions held, as well as market volatility and liquidity. For instruments such as options, the
time period during which the option may be exercised and the relationship between the current market price of the
underlying instrument and the option’s contractual strike or exercise price also affects the level of market risk. A
significant factor influencing the overall level of market risk to which Entergy is exposed is its use of hedging techniques
to mitigate such risk. Hedging instruments and volumes are chosen based on ability to mitigate risk associated with
future energy and capacity prices; however, other considerations are factored into hedge product and volume decisions
including corporate liquidity, corporate credit ratings, counterparty credit risk, hedging costs, firm settlement risk, and
product availability in the marketplace. Entergy manages market risk by actively monitoring compliance with stated
risk management policies as well as monitoring the effectiveness of its hedging policies and strategies. Entergy’s risk
management policies limit the amount of total net exposure and rolling net exposure during the stated periods. These
policies, including related risk limits, are regularly assessed to ensure their appropriateness given Entergy’s objectives.
Derivatives
Some derivative instruments are classified as cash flow hedges due to their financial settlement provisions
while others are classified as normal purchase/normal sale transactions due to their physical settlement
provisions. Normal purchase/normal sale risk management tools include power purchase and sales agreements, fuel
purchase agreements, capacity contracts, and tolling agreements. Financially-settled cash flow hedges can include
204
E-5 Page 152 of 182
Entergy Corporation and Subsidiaries
Notes to Financial
Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc.
41
natural gas and electricity swaps and options and interest rate swaps. Entergy may enter into financially-settled swap
and option contracts to manage market risk that may or may not be designated as hedging instruments.
Entergy enters into derivatives to manage natural risks inherent in its physical or financial assets or liabilities.
Electricity over-the-counter instruments that financially settle against day-ahead power pool prices are used to manage
price exposure for Entergy Wholesale Commodities generation. The maximum length of time over which Entergy is
currently hedging the variability in future cash flows with derivatives for forecasted power transactions at December 31,
2014 is approximately 3 years. Planned generation currently under contract from Entergy Wholesale Commodities
nuclear power plants is 86% for 2015, of which approximately 62% is sold under financial derivatives and the remainder
under normal purchase/normal sale contracts. Total planned generation for 2015 is 35 TWh.
Entergy may use standardized master netting agreements to help mitigate the credit risk of derivative
instruments. These master agreements facilitate the netting of cash flows associated with a single counterparty and
may include collateral requirements. Cash, letters of credit and parental/affiliate guarantees may be obtained as security
from counterparties in order to mitigate credit risk. The collateral agreements require a counterparty to post cash or
letters of credit in the event an exposure exceeds an established threshold. The threshold represents an unsecured credit
limit, which may be supported by a parental/affiliate guaranty, as determined in accordance with Entergy’s credit policy.
In addition, collateral agreements allow for termination and liquidation of all positions in the event of a failure or
inability to post collateral.
Certain of the agreements to sell the power produced by Entergy Wholesale Commodities power plants contain
provisions that require an Entergy subsidiary to provide collateral to secure its obligations when the current market
prices exceed the contracted power prices. The primary form of collateral to satisfy these requirements is an Entergy
Corporation guarantee. As of December 31, 2014, derivative contracts with 1 counterparty were in a liability position
(approximately $1 million total). As of December 31, 2013, derivative contracts with 9 counterparties were in a liability
position (approximately $187 million total). In addition to the corporate guarantee, $47 million in cash collateral was
required to be posted. If the Entergy Corporation credit rating falls below investment grade, the effect of the corporate
guarantee is typically ignored and Entergy would have to post collateral equal to the estimated outstanding liability
under the contract at the applicable date.
Entergy manages fuel price volatility for its Louisiana jurisdictions (Entergy Gulf States Louisiana, Entergy
Louisiana, and Entergy New Orleans) and Entergy Mississippi through the purchase of short-term natural gas swaps
that financially settle against NYMEX futures. These swaps are marked-to-market through fuel expense with offsetting
regulatory assets or liabilities. All benefits or costs of the program are recorded in fuel costs. The notional volumes
of these swaps are based on a portion of projected annual exposure to gas for electric generation and projected winter
purchases for gas distribution at Entergy Gulf States Louisiana and Entergy New Orleans. The total volume of natural
gas swaps outstanding as of December 31, 2014 is 21,475,000 MMBtu for Entergy, including 8,740,000 MMBtu for
Entergy Gulf States Louisiana, 8,810,000 MMBtu for Entergy Louisiana, 3,230,000 MMBtu for Entergy Mississippi,
and 695,000 MMBtu for Entergy New Orleans. Credit support for these natural gas swaps is covered by master
agreements that do not require collateralization based on mark-to-market value, but do carry adequate assurance
language that may lead to collateralization requests.
During the second quarter 2014, Entergy participated in the annual FTR auction process for the MISO planning
year of June 1, 2014 through May 31, 2015. FTRs are derivative instruments which represent economic hedges of
future congestion charges that will be incurred in serving Entergy’s customer load. They are not designated as hedging
instruments. Entergy initially records FTRs at their estimated fair value and subsequently adjusts the carrying value
to their estimated fair value at the end of each accounting period prior to settlement. Unrealized gains or losses on
FTRs held by Entergy Wholesale Commodities are included in operating revenues. The Utility operating companies
recognize regulatory liabilities or assets for unrealized gains or losses on FTRs. The total volume of FTRs outstanding
as of December 31, 2014 is 45,196 GWh for Entergy, including 9,844 GWh for Entergy Arkansas, 9,881 GWh for
Entergy Gulf States Louisiana, 10,691 GWh for Entergy Louisiana, 5,403 GWh for Entergy Mississippi, 3,633 GWh
for Entergy New Orleans, and 5,669 GWh for Entergy Texas. Credit support for FTRs held by the Utility operating
205
E-5 Page 153 of 182
Entergy Corporation and Subsidiaries
Notes to Financial Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41
companies is covered by cash or letters of credit issued by each Utility operating company as required by MISO. Credit
support for FTRs held by Entergy Wholesale Commodities is covered by cash. As of December 31, 2014, letters of
credit posted with MISO covered the FTR exposure for Entergy Arkansas and Entergy Mississippi. No cash collateral
was required to be posted for FTR exposure for the Utility operating companies or Entergy Wholesale Commodities.
The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of December 31, 2014
are shown in the table below. Certain investments, including those not designated as hedging instruments, are subject
to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting
guidance for derivatives and hedging.
Instrument
Balance Sheet Location
Fair
Value (a)
Offset
(b)
Net (c) (d)
(In Millions)
Business
Derivatives designated
as hedging instruments
Assets:
Electricity swaps and
options
Electricity swaps and
options
Liabilities:
Electricity swaps and
options
Prepayments and other
(current portion)
Other deferred debits
and other assets (noncurrent portion)
$149
($53)
$96
Entergy Wholesale
Commodities
Entergy Wholesale
Commodities
$48
$—
$48
Other current liabilities
(current portion)
$24
($24)
$—
Entergy Wholesale
Commodities
Prepayments and other
(current portion)
Other deferred debits
and other assets (noncurrent portion)
Prepayments and other
$97
($25)
$72
$9
($8)
$1
Entergy Wholesale
Commodities
Entergy Wholesale
Commodities
$50
($3)
$47
Utility and Entergy
Wholesale
Commodities
$57
($55)
$2
$8
($8)
$—
Entergy Wholesale
Commodities
Entergy Wholesale
Commodities
$20
$—
$20
Derivatives not
designated as hedging
instruments
Assets:
Electricity swaps and
options
Electricity swaps and
options
FTRs
Liabilities:
Electricity swaps and
options
Electricity swaps and
options
Natural gas swaps
Other current liabilities
(current portion)
Other non-current
liabilities (non-current
portion)
Other current liabilities
206
Utility
E-5 Page 154 of 182
Entergy Corporation and Subsidiaries
Notes to Financial
Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc.
41
The fair values of Entergy’s derivative instruments in the consolidated balance sheet as of December 31, 2013
are shown in the table below. Certain investments, including those not designated as hedging instruments, are subject
to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting
guidance for derivatives and hedging.
Instrument
Balance Sheet Location
Fair
Value (a)
Offset
(b)
Net (c) (d)
(In Millions)
Business
Derivatives designated
as hedging instruments
Assets:
Electricity swaps and
options
Electricity swaps and
options
Prepayments and other
(current portion)
Other deferred debits
and other assets (noncurrent portion)
$118
($99)
$19
$17
($17)
$—
Other current liabilities
(current portion)
$197
($131)
$66
Entergy Wholesale
Commodities
Other non-current
liabilities (non-current
portion)
$46
($17)
$29
Entergy Wholesale
Commodities
Assets:
Electricity swaps and
options
Natural gas swaps
FTRs
Prepayments and other
(current portion)
Prepayments and other
Prepayments and other
$177
($122)
$55
$6
$36
$—
($2)
$6
$34
Entergy Wholesale
Commodities
Utility
Utility and Entergy
Wholesale
Commodities
Liabilities:
Electricity swaps and
options
Other current liabilities
(current portion)
$201
($89)
$112
Entergy Wholesale
Commodities
Liabilities:
Electricity swaps and
options
Electricity swaps and
options
Entergy Wholesale
Commodities
Entergy Wholesale
Commodities
Derivatives not
designated as hedging
instruments
(a)
(b)
(c)
(d)
Represents the gross amounts of recognized assets/liabilities
Represents the netting of fair value balances with the same counterparty
Represents the net amounts of assets/liabilities presented on the Entergy Consolidated Balance Sheets
Excludes cash collateral in the amounts of $25 million held as of December 31, 2014 and $47 million posted
and $4 million held as of December 31, 2013, respectively
207
E-5 Page 155 of 182
Entergy Corporation and Subsidiaries
Notes to Financial Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41
The effect of Entergy’s derivative instruments designated as cash flow hedges on the consolidated income
statements for the years ended December 31, 2014, 2013, and 2012 are as follows:
Instrument
Amount of gain
(loss)
recognized in other
comprehensive
income
(In Millions)
Income Statement location
Amount of gain
(loss) reclassified
from
AOCI into income (a)
(In Millions)
2014
Electricity swaps and options
$81
Competitive business operating
revenues
($193)
2013
Electricity swaps and options
($190)
Competitive business operating
revenues
$47
2012
Electricity swaps and options
$111
Competitive business operating
revenues
$268
(a)
Before taxes of ($68) million, $18 million, and $94 million, for the years ended December 31, 2014, 2013,
and 2012, respectively
At each reporting period, Entergy measures its hedges for ineffectiveness. Any ineffectiveness is recognized
in earnings during the period. The ineffective portion of cash flow hedges is recorded in competitive businesses
operating revenues. The change in fair value of Entergy’s cash flow hedges due to ineffectiveness was $7 million,
($6) million, and ($14) million for the years ended December 31, 2014, 2013, and 2012, respectively.
Based on market prices as of December 31, 2014, unrealized gains recorded in AOCI on cash flow hedges
relating to power sales totaled $156 million of net unrealized gains. Approximately $109 million is expected to be
reclassified from AOCI to operating revenues in the next twelve months. The actual amount reclassified from
AOCI, however, could vary due to future changes in market prices.
Entergy may effectively liquidate a cash flow hedge instrument by entering into a contract offsetting the original
hedge, and then de-designating the original hedge in this situation. Gains or losses accumulated in other comprehensive
income prior to de-designation continue to be deferred in other comprehensive income until they are included in income
as the original hedged transaction occurs. From the point of de-designation, the gains or losses on the original hedge
and the offsetting contract are recorded as assets or liabilities on the balance sheet and offset as they flow through to
earnings.
208
E-5 Page 156 of 182
Entergy Corporation and Subsidiaries
Notes to Financial
Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc.
41
The effect of Entergy’s derivative instruments not designated as hedging instruments on the consolidated
income statements for the years ended December 31, 2014, 2013, and 2012 is as follows:
Instrument
2014
Natural gas swaps
FTRs
Electricity swaps and options
Amount of gain
(loss)
recognized in
AOCI
(In Millions)
—
—
($13)
2013
Natural gas swaps
—
FTRs
Electricity swaps and options
—
$1
2012
Natural gas swaps
—
Electricity swaps and options
$1
(a)
(b)
Amount of gain
(loss)
recorded in the
income statement
(In Millions)
Income Statement
location
Fuel, fuel-related expenses,
and gas purchased for resale
Purchased power expense
Competitive business
operating revenues
(a)
($8)
(b)
$229
$56
Fuel, fuel-related expenses,
and gas purchased for resale
Purchased power
Competitive business
operating revenues
(a)
$13
(b)
$3
($50)
Fuel, fuel-related expenses,
and gas purchased for resale
Competitive business
operating revenues
(a)
($42)
$1
Due to regulatory treatment, the natural gas swaps are marked-to-market through fuel, fuel-related expenses,
and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting
regulatory asset or liability. The gains or losses recorded as fuel expenses when the swaps are settled are
recovered or refunded through fuel cost recovery mechanisms.
Due to regulatory treatment, the changes in the estimated fair value of FTRs for the Utility operating companies
are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded
as an offsetting regulatory asset or liability. The gains or losses recorded as purchased power expense when
the FTRs for the Utility operating companies are settled are recovered or refunded through fuel cost recovery
mechanisms.
209
E-5 Page 157 of 182
Entergy Corporation and Subsidiaries
Notes to Financial Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41
The fair values of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments
on their balance sheets as of December 31, 2014 and 2013 are as follows:
Instrument
Balance Sheet Location
Fair Value (a)
(In Millions)
Registrant
2014
(a)
Assets:
FTRs
FTRs
FTRs
FTRs
FTRs
FTRs
Prepayments and other
Prepayments and other
Prepayments and other
Prepayments and other
Prepayments and other
Prepayments and other
$0.7
$14.4
$11.1
$3.4
$4.1
$12.3
Entergy Arkansas
Entergy Gulf States Louisiana
Entergy Louisiana
Entergy Mississippi
Entergy New Orleans
Entergy Texas
Liabilities:
Natural gas swaps
Natural gas swaps
Natural gas swaps
Natural gas swaps
Other current liabilities
Other current liabilities
Other current liabilities
Other current liabilities
$8.2
$7.6
$2.8
$0.9
Entergy Gulf States Louisiana
Entergy Louisiana
Entergy Mississippi
Entergy New Orleans
2013
Assets:
Natural gas swaps
Natural gas swaps
Natural gas swaps
Natural gas swaps
Gas hedge contracts
Gas hedge contracts
Prepayments and other
Prepayments and other
$2.2
$2.9
$0.7
$0.1
Entergy Gulf States Louisiana
Entergy Louisiana
Entergy Mississippi
Entergy New Orleans
FTRs
FTRs
FTRs
FTRs
FTRs
Prepayments and other
Prepayments and other
Prepayments and other
Prepayments and other
Prepayments and other
$6.7
$5.7
$1.0
$2.0
$18.4
Entergy Gulf States Louisiana
Entergy Louisiana
Entergy Mississippi
Entergy New Orleans
Entergy Texas
No cash collateral was required to be posted as of December 31, 2014 and 2013, respectively.
210
E-5 Page 158 of 182
Entergy Corporation and Subsidiaries
Notes to Financial
Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc.
41
The effects of the Registrant Subsidiaries’ derivative instruments not designated as hedging instruments on
their income statements for the years ended December 31, 2014, 2013, and 2012 are as follows:
Instrument
2014
Natural gas swaps
Natural gas swaps
Natural gas swaps
Natural gas swaps
FTRs
FTRs
FTRs
FTRs
FTRs
FTRs
2013
Natural gas swaps
Natural gas swaps
Natural gas swaps
Natural gas swaps
FTRs
FTRs
FTRs
FTRs
FTRs
FTRs
2012
Natural gas swaps
Natural gas swaps
Natural gas swaps
Natural gas swaps
Income Statement Location
Amount of gain
(loss)
recorded
in the income
statement
(In Millions)
Registrant
Fuel, fuel-related expenses,
and gas purchased for resale
Fuel, fuel-related expenses,
and gas purchased for resale
Fuel, fuel-related expenses,
and gas purchased for resale
Fuel, fuel-related expenses,
and gas purchased for resale
($3.9)
Entergy Gulf States Louisiana
($1.6)
Entergy Louisiana
($2.5)
Entergy Mississippi
($0.2)
Entergy New Orleans
Purchased power
Purchased power
Purchased power
Purchased power
Purchased power
Purchased power
$21.6
$56.3
$47.2
$19.0
$16.5
$65.8
Entergy Arkansas
Entergy Gulf States Louisiana
Entergy Louisiana
Entergy Mississippi
Entergy New Orleans
Entergy Texas
Fuel, fuel-related expenses,
and gas purchased for resale
Fuel, fuel-related expenses,
and gas purchased for resale
Fuel, fuel-related expenses,
and gas purchased for resale
Fuel, fuel-related expenses,
and gas purchased for resale
$4.5
Entergy Gulf States Louisiana
$6.0
Entergy Louisiana
$2.5
Entergy Mississippi
$0.1
Entergy New Orleans
Purchased power
Purchased power
Purchased power
Purchased power
Purchased power
Purchased power
($0.1)
$0.3
$0.2
$1.0
$1.2
$0.8
Entergy Arkansas
Entergy Gulf States Louisiana
Entergy Louisiana
Entergy Mississippi
Entergy New Orleans
Entergy Texas
Fuel, fuel-related expenses,
and gas purchased for resale
Fuel, fuel-related expenses,
and gas purchased for resale
Fuel, fuel-related expenses,
and gas purchased for resale
Fuel, fuel-related expenses,
and gas purchased for resale
($12.9)
Entergy Gulf States Louisiana
($16.2)
Entergy Louisiana
($11.2)
Entergy Mississippi
($1.5)
Entergy New Orleans
211
E-5 Page 159 of 182
Entergy Corporation and Subsidiaries
Notes to Financial Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41
Fair Values
The estimated fair values of Entergy’s financial instruments and derivatives are determined using historical
prices, bid prices, market quotes, and financial modeling. Considerable judgment is required in developing the estimates
of fair value. Therefore, estimates are not necessarily indicative of the amounts that Entergy could realize in a current
market exchange. Gains or losses realized on financial instruments other than those instruments held by the Entergy
Wholesale Commodities business are reflected in future rates and therefore do not affect net income. Entergy considers
the carrying amounts of most financial instruments classified as current assets and liabilities to be a reasonable estimate
of their fair value because of the short maturity of these instruments.
Accounting standards define fair value as an exit price, or the price that would be received to sell an asset or
the amount that would be paid to transfer a liability in an orderly transaction between knowledgeable market participants
at the date of measurement. Entergy and the Registrant Subsidiaries use assumptions or market input data that market
participants would use in pricing assets or liabilities at fair value. The inputs can be readily observable, corroborated
by market data, or generally unobservable. Entergy and the Registrant Subsidiaries endeavor to use the best available
information to determine fair value.
Accounting standards establish a fair value hierarchy that prioritizes the inputs used to measure fair value. The
hierarchy establishes the highest priority for unadjusted market quotes in an active market for the identical asset or
liability and the lowest priority for unobservable inputs. The three levels of the fair value hierarchy are:
•
Level 1 - Level 1 inputs are unadjusted quoted prices in active markets for identical assets or liabilities that the
entity has the ability to access at the measurement date. Active markets are those in which transactions for the
asset or liability occur in sufficient frequency and volume to provide pricing information on an ongoing basis. Level
1 primarily consists of individually owned common stocks, cash equivalents (temporary cash investments,
securitization recovery trust account, and escrow accounts), debt instruments, and gas hedge contracts. Cash
equivalents includes all unrestricted highly liquid debt instruments with an original or remaining maturity of three
months or less at the date of purchase.
•
Level 2 - Level 2 inputs are inputs other than quoted prices included in Level 1 that are, either directly or indirectly,
observable for the asset or liability at the measurement date. Assets are valued based on prices derived by
independent third parties that use inputs such as benchmark yields, reported trades, broker/dealer quotes, and issuer
spreads. Prices are reviewed and can be challenged with the independent parties and/or overridden by Entergy if
it is believed such would be more reflective of fair value. Level 2 inputs include the following:
-
quoted prices for similar assets or liabilities in active markets;
quoted prices for identical assets or liabilities in inactive markets;
inputs other than quoted prices that are observable for the asset or liability; or
inputs that are derived principally from or corroborated by observable market data by correlation or
other means.
Level 2 consists primarily of individually-owned debt instruments or shares in common trusts. Common trust funds
are stated at estimated fair value based on the fair market value of the underlying investments.
•
Level 3 - Level 3 inputs are pricing inputs that are generally less observable or unobservable from objective
sources. These inputs are used with internally developed methodologies to produce management’s best estimate
of fair value for the asset or liability. Level 3 consists primarily of FTRs and derivative power contracts used as
cash flow hedges of power sales at merchant power plants.
The values for power contract assets or liabilities are based on both observable inputs including public market
prices and interest rates, and unobservable inputs such as implied volatilities, unit contingent discounts, expected basis
differences, and credit adjusted counterparty interest rates. They are classified as Level 3 assets and liabilities. The
212
E-5 Page 160 of 182
Entergy Corporation and Subsidiaries
Notes to Financial
Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc.
41
valuations of these assets and liabilities are performed by the Entergy Wholesale Commodities Risk Control group and
the Entergy Wholesale Commodities Accounting Policy and External Reporting group. The primary functions of the
Entergy Wholesale Commodities Risk Control group include: gathering, validating and reporting market data, providing
market risk analyses and valuations in support of Entergy Wholesale Commodities’ commercial transactions,
developing and administering protocols for the management of market risks, and implementing and maintaining controls
around changes to market data in the energy trading and risk management system. The Risk Control group is also
responsible for managing the energy trading and risk management system, forecasting revenues, forward positions and
analysis. The Entergy Wholesale Commodities Accounting Policy and External Reporting group performs functions
related to market and counterparty settlements, revenue reporting and analysis and financial accounting. The Entergy
Wholesale Commodities Risk Control group reports to the Vice President and Treasurer while the Entergy Wholesale
Commodities Accounting Policy and External Reporting group reports to the Vice President, Accounting Policy and
External Reporting.
The amounts reflected as the fair value of electricity swaps are based on the estimated amount that the contracts
are in-the-money at the balance sheet date (treated as an asset) or out-of-the-money at the balance sheet date (treated
as a liability) and would equal the estimated amount receivable to or payable by Entergy if the contracts were settled
at that date. These derivative contracts include cash flow hedges that swap fixed for floating cash flows for sales of
the output from the Entergy Wholesale Commodities business. The fair values are based on the mark-to-market
comparison between the fixed contract prices and the floating prices determined each period from quoted forward
power market prices. The differences between the fixed price in the swap contract and these market-related prices
multiplied by the volume specified in the contract and discounted at the counterparties’ credit adjusted risk free rate
are recorded as derivative contract assets or liabilities. For contracts that have unit contingent terms, a further discount
is applied based on the historical relationship between contract and market prices for similar contract terms.
The amounts reflected as the fair values of electricity options are valued based on a Black Scholes model, and
are calculated at the end of each month for accounting purposes. Inputs to the valuation include end of day forward
market prices for the period when the transactions will settle, implied volatilities based on market volatilities provided
by a third party data aggregator, and US Treasury rates for a risk-free return rate. As described further below, prices
and implied volatilities are reviewed and can be adjusted if it is determined that there is a better representation of fair
value.
On a daily basis, Entergy Wholesale Commodities Risk Control group calculates the mark-to-market for
electricity swaps and options. Entergy Wholesale Commodities Risk Control group also validates forward market
prices by comparing them to other sources of forward market prices or to settlement prices of actual market
transactions. Significant differences are analyzed and potentially adjusted based on these other sources of forward
market prices or settlement prices of actual market transactions. Implied volatilities used to value options are also
validated using actual counterparty quotes for Entergy Wholesale Commodities transactions when available, and uses
multiple sources of market implied volatilities. Moreover, on at least a monthly basis, the Office of Corporate Risk
Oversight confirms the mark-to-market calculations and prepares price scenarios and credit downgrade scenario
analysis. The scenario analysis is communicated to senior management within Entergy and within Entergy Wholesale
Commodities. Finally, for all proposed derivative transactions, an analysis is completed to assess the risk of adding
the proposed derivative to Entergy Wholesale Commodities’ portfolio. In particular, the credit and liquidity effects
are calculated for this analysis. This analysis is communicated to senior management within Entergy and Entergy
Wholesale Commodities.
The values of FTRs are based on unobservable inputs, including estimates of future congestion costs in MISO
between applicable generation and load pricing nodes based on prices published by MISO. They are classified as
Level 3 assets and liabilities. The valuations of these assets and liabilities are performed by the Entergy Wholesale
Commodities Risk Control group for the unregulated business and by the System Planning and Operations Risk Control
group for the Utility operating companies. Entergy’s Accounting Policy group reviews these valuations for
reasonableness, with the assistance of others within the organization with knowledge of the various inputs and
213
E-5 Page 161 of 182
Entergy Corporation and Subsidiaries
Notes to Financial Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41
assumptions used in the valuation. The System Planning and Operations Risk Control group reports to the Vice President
and Treasurer. The Accounting Policy group reports to the Vice President, Accounting Policy and External Reporting.
The following tables set forth, by level within the fair value hierarchy, Entergy’s assets and liabilities that are
accounted for at fair value on a recurring basis as of December 31, 2014 and December 31, 2013. The assessment of
the significance of a particular input to a fair value measurement requires judgment and may affect their placement
within the fair value hierarchy levels.
2014
Assets:
Temporary cash investments
Decommissioning trust funds (a):
Equity securities
Debt securities
Power contracts
Securitization recovery trust account
Escrow accounts
FTRs
Level 1
$—
$—
$1,291
452
880
—
44
362
—
$3,029
2,834 (b)
1,205
—
—
—
—
$4,039
—
—
217
—
—
47
$264
3,286
2,085
217
44
362
47
$7,332
$2
—
$2
$2
20
$22
$—
20
$20
Assets:
Temporary cash investments
Decommissioning trust funds (a):
Equity securities
Debt securities
Power contracts
Securitization recovery trust account
Escrow accounts
Gas hedge contracts
FTRs
Level 1
$609
472
783
—
46
115
6
—
$2,031
Liabilities:
Power contracts
(a)
(b)
Total
$1,291
Liabilities:
Power contracts
Gas hedge contracts
2013
Level 2
Level 3
(In Millions)
$—
$—
—
$—
Level 2
Level 3
(In Millions)
Total
$—
$—
$609
2,601 (b)
1,047
—
—
—
—
—
$3,648
—
—
74
—
—
—
34
$108
3,073
1,830
74
46
115
6
34
$5,787
$—
$207
$207
The decommissioning trust funds hold equity and fixed income securities. Equity securities are invested to
approximate the returns of major market indices. Fixed income securities are held in various governmental
and corporate securities. See Note 17 to the financial statements for additional information on the investment
portfolios.
Commingled equity funds may be redeemed semi-monthly.
214
E-5 Page 162 of 182
Entergy Corporation and Subsidiaries
Notes to Financial
Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc.
41
The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of
derivatives classified as Level 3 in the fair value hierarchy for the years ended December 31, 2014, 2013, and 2012:
2014
Power
Contracts
Balance as of January 1,
Realized losses included in earnings
Unrealized gains (losses) included
in earnings
Unrealized gains (losses) included
in OCI
Unrealized gains included as a
regulatory liability / asset
Issuances of FTRs
Purchases
Settlements
Balance as of December 31,
2013
Power
Contracts
(In Millions)
FTRs
2012
Power
Contracts
FTRs
($133)
(65)
120
$34
—
2
$178
(38)
(35)
$—
—
—
$312
(11)
(4)
131
—
(204)
—
140
—
119
—
—
—
—
17
145
$215
121
—
(229)
$47
—
14
(48)
($133)
37
—
(3)
$34
—
9
(268)
$178
The following table sets forth a description of the types of transactions classified as Level 3 in the fair value
hierarchy and significant unobservable inputs to each which cause that classification, as of December 31, 2014:
Transaction Type
Electricity swaps
Electricity options
Fair Value
as of
December 31,
2014
(In Millions)
$165
$50
Significant
Unobservable Inputs
Range
from
Average
%
Unit contingent discount
Implied volatility
+/-3%
+/-130%
Effect on
Fair Value
(In Millions)
$10
$43
The following table sets forth an analysis of each of the types of unobservable inputs impacting the fair value of
items classified as Level 3 within the fair value hierarchy, and the sensitivity to changes to those inputs:
Significant
Unobservable
Input
Transaction Type
Position
Change to Input
Effect on
Fair Value
Unit contingent discount
Implied volatility
Implied volatility
Electricity swaps
Electricity options
Electricity options
Sell
Sell
Buy
Increase (Decrease)
Increase (Decrease)
Increase (Decrease)
Decrease (Increase)
Increase (Decrease)
Increase (Decrease)
215
E-5 Page 163 of 182
Entergy Corporation and Subsidiaries
Notes to Financial Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41
The following table sets forth, by level within the fair value hierarchy, the Registrant Subsidiaries’ assets that
are accounted for at fair value on a recurring basis as of December 31, 2014 and December 31, 2013. The assessment
of the significance of a particular input to a fair value measurement requires judgment and may affect its placement
within the fair value hierarchy levels.
Entergy Arkansas
2014
Assets:
Temporary cash investments
Decommissioning trust funds (a):
Equity securities
Debt securities
Securitization recovery trust account
Escrow accounts
FTRs
2013
Assets:
Temporary cash investments
Decommissioning trust funds (a):
Equity securities
Debt securities
Securitization recovery trust account
Escrow accounts
Level 1
$208.0
7.2
72.2
4.1
12.2
—
$303.7
Level 1
$122.8
13.6
58.6
3.8
26.0
$224.8
Level 2
Level 3
(In Millions)
$—
480.1 (b)
210.4
—
—
—
$690.5
$—
$208.0
—
—
—
—
0.7
$0.7
487.3
282.6
4.1
12.2
0.7
$994.9
Level 2
Level 3
(In Millions)
$—
449.7 (b)
189.0
—
—
$638.7
Total
Total
$—
$122.8
—
—
—
—
$—
463.3
247.6
3.8
26.0
$863.5
Entergy Gulf States Louisiana
2014
Assets:
Temporary cash investments
Decommissioning trust funds (a):
Equity securities
Debt securities
Escrow accounts
FTRs
Liabilities:
Gas hedge contracts
Level 1
$109.6
10.5
81.9
90.1
—
$292.1
$8.2
216
Level 2
Level 3
(In Millions)
$—
385.4 (b)
159.9
—
—
$545.3
$—
Total
$—
$109.6
—
—
—
14.4
$14.4
395.9
241.8
90.1
14.4
$851.8
$—
$8.2
E-5 Page 164 of 182
Entergy Corporation and Subsidiaries
Notes to Financial
Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc.
41
2013
Assets:
Temporary cash investments
Decommissioning trust funds (a):
Equity securities
Debt securities
Escrow accounts
Gas hedge contracts
FTRs
Level 1
$13.8
27.6
71.7
21.5
2.2
—
$136.8
Level 2
Level 3
(In Millions)
$—
343.2 (b)
131.2
—
—
—
$474.4
Total
$—
$13.8
—
—
—
—
6.7
$6.7
370.8
202.9
21.5
2.2
6.7
$617.9
Entergy Louisiana
2014
Assets:
Temporary cash investments
Decommissioning trust funds (a):
Equity securities
Debt securities
Securitization recovery trust account
Escrow accounts
FTRs
Liabilities:
Gas hedge contracts
2013
Assets:
Temporary cash investments
Decommissioning trust funds (a):
Equity securities
Debt securities
Securitization recovery trust account
Gas hedge contracts
FTRs
Level 1
$157.1
4.8
68.7
3.1
200.1
—
$433.8
$7.6
Level 1
$123.6
13.5
61.7
4.5
2.9
—
$206.2
217
Level 2
Level 3
(In Millions)
$—
234.8 (b)
75.3
—
—
—
$310.1
$—
$—
$157.1
—
—
—
—
11.1
$11.1
239.6
144.0
3.1
200.1
11.1
$755.0
$—
$7.6
Level 2
Level 3
(In Millions)
$—
210.7 (b)
61.4
—
—
—
$272.1
Total
Total
$—
$123.6
—
—
—
—
5.7
$5.7
224.2
123.1
4.5
2.9
5.7
$484.0
E-5 Page 165 of 182
Entergy Corporation and Subsidiaries
Notes to Financial Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41
Entergy Mississippi
2014
Level 1
Level 2
Level 3
(In Millions)
Total
Assets:
Temporary cash investments
Escrow accounts
FTRs
Liabilities:
Gas hedge contracts
2013
Assets:
Escrow accounts
Gas hedge contracts
FTRs
$60.4
41.8
—
$102.2
$—
—
—
$—
$—
—
3.4
$3.4
$60.4
41.8
3.4
$105.6
$2.8
$—
$—
$2.8
Level 1
$51.8
0.7
—
$52.5
Level 2
Level 3
(In Millions)
$—
—
—
$—
$—
—
1.0
$1.0
Total
$51.8
0.7
1.0
$53.5
Entergy New Orleans
2014
Assets:
Temporary cash investments
Escrow accounts
FTRs
Liabilities:
Gas hedge contracts
2013
Assets:
Temporary cash investments
Escrow accounts
Gas hedge contracts
FTRs
Level 1
Level 2
Level 3
(In Millions)
Total
$41.4
18.0
—
$59.4
$—
—
—
$—
$—
—
4.1
$4.1
$41.4
18.0
4.1
$63.5
$0.9
$—
$—
$0.9
Level 1
$33.2
10.5
0.1
—
$43.8
218
Level 2
Level 3
(In Millions)
$—
—
—
—
$—
$—
—
—
2.0
$2.0
Total
$33.2
10.5
0.1
2.0
$45.8
E-5 Page 166 of 182
Entergy Corporation and Subsidiaries
Notes to Financial
Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc.
41
Entergy Texas
2014
Assets:
Temporary cash investments
Securitization recovery trust account
FTRs
2013
Assets:
Temporary cash investments
Securitization recovery trust account
FTRs
Level 1
$28.7
37.2
—
$65.9
Level 1
$44.1
37.5
—
$81.6
Level 2
Level 3
(In Millions)
$—
—
—
$—
Total
$—
—
12.3
$12.3
Level 2
Level 3
(In Millions)
$—
—
—
$—
$28.7
37.2
12.3
$78.2
Total
$—
—
18.4
$18.4
$44.1
37.5
18.4
$100.0
System Energy
2014
Assets:
Temporary cash investments
Decommissioning trust funds (a):
Equity securities
Debt securities
2013
Assets:
Temporary cash investments
Decommissioning trust funds (a):
Equity securities
Debt securities
(a)
(b)
Level 1
$222.4
2.0
194.2
$418.6
Level 1
$64.6
2.2
152.9
$219.7
Level 2
Level 3
(In Millions)
$—
422.5 (b)
61.1
$483.6
$—
$222.4
—
—
$—
424.5
255.3
$902.2
Level 2
Level 3
(In Millions)
$—
377.8 (b)
71.0
$448.8
Total
Total
$—
$64.6
—
—
$—
380.0
223.9
$668.5
The decommissioning trust funds hold equity and fixed income securities. Equity securities are invested to
approximate the returns of major market indices. Fixed income securities are held in various governmental
and corporate securities. See Note 17 to the financial statements for additional information on the investment
portfolios.
Commingled equity funds may be redeemed semi-monthly.
219
E-5 Page 167 of 182
Entergy Corporation and Subsidiaries
Notes to Financial Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41
The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of
derivatives classified as Level 3 in the fair value hierarchy for the year ended December 31, 2014.
Entergy
Arkansas
Balance as of January 1,
Issuances of FTRs
Unrealized gains (losses) included
as a regulatory liability / asset
Settlements
Balance as of December 31,
Entergy
Gulf States Entergy
Entergy
Louisiana Louisiana Mississippi
(In Millions)
Entergy
New
Orleans
Entergy
Texas
$—
4.2
18.1
$6.7
37.3
26.7
$5.7
21.5
31.1
$1.0
15.2
6.2
$2.0
8.3
10.3
$18.4
33.2
26.5
(21.6)
$0.7
(56.3)
$14.4
(47.2)
$11.1
(19.0)
$3.4
(16.5)
$4.1
(65.8)
$12.3
The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of
derivatives classified as Level 3 in the fair value hierarchy for the year ended December 31, 2013.
Entergy
Arkansas
Balance as of January 1,
Issuances of FTRs
Unrealized gains (losses) included
as a regulatory liability / asset
Settlements
Balance as of December 31,
Entergy
Gulf States Entergy
Entergy
Louisiana Louisiana Mississippi
(In Millions)
Entergy
New
Orleans
Entergy
Texas
$—
—
(0.1)
$—
7.2
(0.2)
$—
6.2
(0.3)
$—
1.1
0.9
$—
2.2
1.0
$—
20.0
(0.8)
0.1
$—
(0.3)
$6.7
(0.2)
$5.7
(1.0)
$1.0
(1.2)
$2.0
(0.8)
$18.4
NOTE 17. DECOMMISSIONING TRUST FUNDS (Entergy Corporation, Entergy Arkansas, Entergy Gulf
States Louisiana, Entergy Louisiana, and System Energy)
Entergy holds debt and equity securities, classified as available-for-sale, in nuclear decommissioning trust
accounts. The NRC requires Entergy subsidiaries to maintain trusts to fund the costs of decommissioning ANO 1,
ANO 2, River Bend, Waterford 3, Grand Gulf, Pilgrim, Indian Point 1 and 2, Vermont Yankee, and Palisades (NYPA
currently retains the decommissioning trusts and liabilities for Indian Point 3 and FitzPatrick). The funds are invested
primarily in equity securities, fixed-rate debt securities, and cash and cash equivalents.
Entergy records decommissioning trust funds on the balance sheet at their fair value. Because of the ability
of the Registrant Subsidiaries to recover decommissioning costs in rates and in accordance with the regulatory treatment
for decommissioning trust funds, the Registrant Subsidiaries have recorded an offsetting amount of unrealized gains/
(losses) on investment securities in other regulatory liabilities/assets. For the 30% interest in River Bend formerly
owned by Cajun, Entergy Gulf States Louisiana has recorded an offsetting amount of unrealized gains/(losses) in other
deferred credits. Decommissioning trust funds for Pilgrim, Indian Point 1 and 2, Vermont Yankee, and Palisades do
not meet the criteria for regulatory accounting treatment. Accordingly, unrealized gains recorded on the assets in these
trust funds are recognized in the accumulated other comprehensive income component of shareholders’ equity because
these assets are classified as available for sale. Unrealized losses (where cost exceeds fair market value) on the assets
in these trust funds are also recorded in the accumulated other comprehensive income component of shareholders’
equity unless the unrealized loss is other than temporary and therefore recorded in earnings. Generally, Entergy records
220
E-5 Page 168 of 182
Entergy Corporation and Subsidiaries
Notes to Financial
Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc.
41
realized gains and losses on its debt and equity securities using the specific identification method to determine the cost
basis of its securities.
The securities held as of December 31, 2014 and 2013 are summarized as follows:
Fair
Value
2014
Equity Securities
Debt Securities
Total
$3,286
2,085
$5,371
Fair
Value
2013
Equity Securities
Debt Securities
Total
$3,073
1,830
$4,903
Total
Unrealized
Gains
(In Millions)
Total
Unrealized
Losses
$1,513
76
$1,589
$1
6
$7
Total
Unrealized
Gains
(In Millions)
Total
Unrealized
Losses
$1,260
47
$1,307
$—
29
$29
Deferred taxes on unrealized gains/(losses) are recorded in other comprehensive income for the decommissioning trusts
which do not meet the criteria for regulatory accounting treatment as described above. Unrealized gains/(losses) above
are reported before deferred taxes of $396 million and $329 million as of December 31, 2014 and 2013,
respectively. The amortized cost of debt securities was $2,019 million as of December 31, 2014 and $1,843 million
as of December 31, 2013. As of December 31, 2014, the debt securities have an average coupon rate of approximately
3.31%, an average duration of approximately 5.65 years, and an average maturity of approximately 8.45 years. The
equity securities are generally held in funds that are designed to approximate or somewhat exceed the return of the
Standard & Poor’s 500 Index. A relatively small percentage of the equity securities are held in funds intended to
replicate the return of the Wilshire 4500 Index or the Russell 3000 Index.
The fair value and gross unrealized losses of available-for-sale equity and debt securities, summarized by
investment type and length of time that the securities have been in a continuous loss position, are as follows as of
December 31, 2014:
Less than 12 months
More than 12 months
Total
Equity Securities
Debt Securities
Gross
Gross
Fair
Unrealized
Fair
Unrealized
Value
Losses
Value
Losses
(In Millions)
$9
$1
$277
$2
—
—
163
4
$9
$1
$440
$6
221
E-5 Page 169 of 182
Entergy Corporation and Subsidiaries
Notes to Financial Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41
The fair value and gross unrealized losses of available-for-sale equity and debt securities, summarized by
investment type and length of time that the securities have been in a continuous loss position, are as follows as of
December 31, 2013:
Less than 12 months
More than 12 months
Total
Equity Securities
Debt Securities
Gross
Gross
Fair
Unrealized
Fair
Unrealized
Value
Losses
Value
Losses
(In Millions)
$—
$—
$892
$24
—
—
60
5
$—
$—
$952
$29
The unrealized losses in excess of twelve months on equity securities above relate to Entergy’s Utility operating
companies and System Energy.
The fair value of debt securities, summarized by contractual maturities, as of December 31, 2014 and 2013
are as follows:
2014
2013
(In Millions)
$94
$83
783
752
681
620
173
169
79
52
275
154
$2,085
$1,830
less than 1 year
1 year - 5 years
5 years - 10 years
10 years - 15 years
15 years - 20 years
20 years+
Total
During the years ended December 31, 2014, 2013, and 2012, proceeds from the dispositions of securities
amounted to $1,872 million, $2,032 million, and $2,074 million, respectively. During the years ended December 31,
2014, 2013, and 2012, gross gains of $39 million, $91 million, and $39 million, respectively, and gross losses of $8
million, $11 million, and $7 million, respectively, were reclassified out of other comprehensive income into earnings.
222
E-5 Page 170 of 182
Entergy Corporation and Subsidiaries
Notes to Financial
Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc.
41
Entergy Arkansas
Entergy Arkansas holds debt and equity securities, classified as available-for-sale, in nuclear decommissioning
trust accounts. The securities held as of December 31, 2014 and 2013 are summarized as follows:
Total
Unrealized
Gains
(In Millions)
Total
Unrealized
Losses
$487.3
282.6
$769.9
$248.9
6.2
$255.1
$—
1.1
$1.1
$463.3
247.6
$710.9
$214.0
5.3
$219.3
$—
5.2
$5.2
Fair
Value
2014
Equity Securities
Debt Securities
Total
2013
Equity Securities
Debt Securities
Total
The amortized cost of debt securities was $277.4 million as of December 31, 2014 and $248.9 million as of December 31,
2013. As of December 31, 2014, the debt securities have an average coupon rate of approximately 2.55%, an average
duration of approximately 4.68 years, and an average maturity of approximately 5.32 years. The equity securities are
generally held in funds that are designed to approximate the return of the Standard & Poor’s 500 Index. A relatively
small percentage of the equity securities are held in funds intended to replicate the return of the Wilshire 4500 Index.
The fair value and gross unrealized losses of available-for-sale equity and debt securities, summarized by
investment type and length of time that the securities have been in a continuous loss position, are as follows as of
December 31, 2014:
Less than 12 months
More than 12 months
Total
Equity Securities
Debt Securities
Gross
Gross
Fair
Unrealized
Fair
Unrealized
Value
Losses
Value
Losses
(In Millions)
$0.1
$—
$56.5
$0.3
—
—
34.8
0.8
$0.1
$—
$91.3
$1.1
The fair value and gross unrealized losses of available-for-sale equity and debt securities, summarized by
investment type and length of time that the securities have been in a continuous loss position, are as follows as of
December 31, 2013:
Less than 12 months
More than 12 months
Total
Equity Securities
Debt Securities
Gross
Gross
Fair
Unrealized
Fair
Unrealized
Value
Losses
Value
Losses
(In Millions)
$—
$—
$153.2
$4.8
—
—
6.9
0.4
$—
$—
$160.1
$5.2
223
E-5 Page 171 of 182
Entergy Corporation and Subsidiaries
Notes to Financial Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41
The fair value of debt securities, summarized by contractual maturities, as of December 31, 2014 and 2013
are as follows:
2014
2013
(In Millions)
$14.9
$8.1
127.3
110.9
128.2
118.0
1.7
3.9
1.0
0.9
9.5
5.8
$282.6
$247.6
less than 1 year
1 year - 5 years
5 years - 10 years
10 years - 15 years
15 years - 20 years
20 years+
Total
During the years ended December 31, 2014, 2013, and 2012, proceeds from the dispositions of securities
amounted to $181.5 million, $266.4 million, and $144.3 million, respectively. During the years ended December 31,
2014, 2013, and 2012, gross gains of $8.7 million, $16.8 million, and $3.4 million, respectively, and gross losses of
$0.3 million, $0.6 million, and $0.1 million, respectively, were recorded in earnings.
Entergy Gulf States Louisiana
Entergy Gulf States Louisiana holds debt and equity securities, classified as available-for-sale, in nuclear
decommissioning trust accounts. The securities held as of December 31, 2014 and 2013 are summarized as follows:
Total
Unrealized
Gains
(In Millions)
Total
Unrealized
Losses
$395.9
241.8
$637.7
$177.6
11.9
$189.5
$—
0.3
$0.3
$370.8
202.9
$573.7
$141.8
7.4
$149.2
$—
3.5
$3.5
Fair
Value
2014
Equity Securities
Debt Securities
Total
2013
Equity Securities
Debt Securities
Total
The amortized cost of debt securities was $231.5 million as of December 31, 2014 and $199.1 million as of December 31,
2013. As of December 31, 2014, the debt securities have an average coupon rate of approximately 4.40%, an average
duration of approximately 5.87 years, and an average maturity of approximately 11.13 years. The equity securities
are generally held in funds that are designed to approximate the return of the Standard & Poor’s 500 Index. A relatively
small percentage of the equity securities are held in funds intended to replicate the return of the Wilshire 4500 Index.
224
E-5 Page 172 of 182
Entergy Corporation and Subsidiaries
Notes to Financial
Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc.
41
The fair value and gross unrealized losses of available-for-sale equity and debt securities, summarized by
investment type and length of time that the securities have been in a continuous loss position, are as follows as of
December 31, 2014:
Less than 12 months
More than 12 months
Total
Equity Securities
Debt Securities
Gross
Gross
Fair
Unrealized
Fair
Unrealized
Value
Losses
Value
Losses
(In Millions)
$0.1
$—
$14.0
$0.1
—
—
15.0
0.2
$0.1
$—
$29.0
$0.3
The fair value and gross unrealized losses of available-for-sale equity and debt securities, summarized by
investment type and length of time that the securities have been in a continuous loss position, are as follows as of
December 31, 2013:
Less than 12 months
More than 12 months
Total
Equity Securities
Debt Securities
Gross
Gross
Fair
Unrealized
Fair
Unrealized
Value
Losses
Value
Losses
(In Millions)
$—
$—
$91.9
$3.1
—
—
4.6
0.4
$—
$—
$96.5
$3.5
The fair value of debt securities, summarized by contractual maturities, as of December 31, 2014 and 2013
are as follows:
2014
2013
(In Millions)
$6.4
$7.9
59.8
51.2
68.3
75.5
43.6
55.8
14.8
4.6
48.9
7.9
$241.8
$202.9
less than 1 year
1 year - 5 years
5 years - 10 years
10 years - 15 years
15 years - 20 years
20 years+
Total
During the years ended December 31, 2014, 2013, and 2012, proceeds from the dispositions of securities
amounted to $173.5 million, $193.8 million, and $131.0 million, respectively. During the years ended December 31,
2014, 2013, and 2012, gross gains of $1.9 million, $16.0 million, and $6.7 million, respectively, and gross losses of
$0.3 million, $0.1 million, and $0.04 million, respectively, were recorded in earnings.
225
E-5 Page 173 of 182
Entergy Corporation and Subsidiaries
Notes to Financial Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41
Entergy Louisiana
Entergy Louisiana holds debt and equity securities, classified as available-for-sale, in nuclear decommissioning
trust accounts. The securities held as of December 31, 2014 and 2013 are summarized as follows:
Total
Unrealized
Gains
(In Millions)
Total
Unrealized
Losses
$239.6
144.0
$383.6
$116.7
6.9
$123.6
$—
0.4
$0.4
$224.2
123.1
$347.3
$96.1
4.7
$100.8
$—
1.9
$1.9
Fair
Value
2014
Equity Securities
Debt Securities
Total
2013
Equity Securities
Debt Securities
Total
The amortized cost of debt securities was $137.9 million as of December 31, 2014 and $120.6 million as of December 31,
2013. As of December 31, 2014, the debt securities have an average coupon rate of approximately 3.05%, an average
duration of approximately 5.39 years, and an average maturity of approximately 8.39 years. The equity securities are
generally held in funds that are designed to approximate the return of the Standard & Poor’s 500 Index. A relatively
small percentage of the equity securities are held in funds intended to replicate the return of the Wilshire 4500 Index.
The fair value and gross unrealized losses of available-for-sale equity and debt securities, summarized by
investment type and length of time that the securities have been in a continuous loss position, are as follows as of
December 31, 2014:
Less than 12 months
More than 12 months
Total
Equity Securities
Debt Securities
Gross
Gross
Fair
Unrealized
Fair
Unrealized
Value
Losses
Value
Losses
(In Millions)
$0.1
$—
$19.1
$0.1
—
—
12.1
0.3
$0.1
$—
$31.2
$0.4
The fair value and gross unrealized losses of available-for-sale equity and debt securities, summarized by
investment type and length of time that the securities have been in a continuous loss position, are as follows as of
December 31, 2013:
Less than 12 months
More than 12 months
Total
Equity Securities
Debt Securities
Gross
Gross
Fair
Unrealized
Fair
Unrealized
Value
Losses
Value
Losses
(In Millions)
$—
$—
$38.3
$1.7
—
—
1.7
0.2
$—
$—
$40.0
$1.9
226
E-5 Page 174 of 182
Entergy Corporation and Subsidiaries
Notes to Financial
Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc.
41
The fair value of debt securities, summarized by contractual maturities, as of December 31, 2014 and 2013
are as follows:
2014
2013
(In Millions)
$5.6
$14.8
58.2
41.9
44.2
37.0
7.3
6.6
9.4
6.2
19.3
16.6
$144.0
$123.1
less than 1 year
1 year - 5 years
5 years - 10 years
10 years - 15 years
15 years - 20 years
20 years+
Total
During the years ended December 31, 2014, 2013, and 2012, proceeds from the dispositions of securities
amounted to $43.2 million, $109.9 million, and $27.6 million, respectively. During the years ended December 31,
2014, 2013, and 2012, gross gains of $0.3 million, $6.0 million, and $0.2 million, respectively, and gross losses of
$0.02 million, $0.1 million, and $0.04 million, respectively, were recorded in earnings.
System Energy
System Energy holds debt and equity securities, classified as available-for-sale, in nuclear decommissioning
trust accounts. The securities held as of December 31, 2014 and 2013 are summarized as follows:
Total
Unrealized
Gains
(In Millions)
Total
Unrealized
Losses
$424.5
255.3
$679.8
$188.0
5.9
$193.9
$—
0.3
$0.3
$380.0
223.9
$603.9
$150.8
3.5
$154.3
$—
1.8
$1.8
Fair
Value
2014
Equity Securities
Debt Securities
Total
2013
Equity Securities
Debt Securities
Total
The amortized cost of debt securities was $251 million as of December 31, 2014 and $223.4 million as of December 31,
2013. As of December 31, 2014, the debt securities have an average coupon rate of approximately 2.23%, an average
duration of approximately 4.48 years, and an average maturity of approximately 5.95 years. The equity securities are
generally held in funds that are designed to approximate the return of the Standard & Poor’s 500 Index. A relatively
small percentage of the equity securities are held in funds intended to replicate the return of the Wilshire 4500 Index.
227
E-5 Page 175 of 182
Entergy Corporation and Subsidiaries
Notes to Financial Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41
The fair value and gross unrealized losses of available-for-sale equity and debt securities, summarized by
investment type and length of time that the securities have been in a continuous loss position, are as follows as of
December 31, 2014:
Less than 12 months
More than 12 months
Total
Equity Securities
Debt Securities
Gross
Gross
Fair
Unrealized
Fair
Unrealized
Value
Losses
Value
Losses
(In Millions)
$0.1
$—
$51.6
$0.2
—
—
6.5
0.1
$0.1
$—
$58.1
$0.3
The fair value and gross unrealized losses of available-for-sale equity and debt securities, summarized by
investment type and length of time that the securities have been in a continuous loss position, are as follows as of
December 31, 2013:
Less than 12 months
More than 12 months
Total
Equity Securities
Debt Securities
Gross
Gross
Fair
Unrealized
Fair
Unrealized
Value
Losses
Value
Losses
(In Millions)
$—
$—
$121.7
$1.7
—
—
0.9
0.1
$—
$—
$122.6
$1.8
The fair value of debt securities, summarized by contractual maturities, as of December 31, 2014 and 2013
are as follows:
2014
2013
(In Millions)
$33.5
$5.5
139.7
144.9
53.5
44.3
3.4
9.3
3.2
1.6
22.0
18.3
$255.3
$223.9
less than 1 year
1 year - 5 years
5 years - 10 years
10 years - 15 years
15 years - 20 years
20 years+
Total
During the years ended December 31, 2014, 2013, and 2012, proceeds from the dispositions of securities
amounted to $392.9 million, $215.5 million, and $349.4 million, respectively. During the years ended December 31,
2014, 2013, and 2012, gross gains of $1.8 million, $1.5 million, and $3.6 million, respectively, and gross losses of $0.9
million, $1.3 million, and $0.3 million, respectively, were recorded in earnings.
Other-than-temporary impairments and unrealized gains and losses
Entergy, Entergy Arkansas, Entergy Gulf States Louisiana, Entergy Louisiana, and System Energy evaluate
unrealized losses at the end of each period to determine whether an other-than-temporary impairment has occurred. The
assessment of whether an investment in a debt security has suffered an other-than-temporary impairment is based on
whether Entergy has the intent to sell or more likely than not will be required to sell the debt security before recovery
228
E-5 Page 176 of 182
Entergy Corporation and Subsidiaries
Notes to Financial
Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc.
41
of its amortized costs. Further, if Entergy does not expect to recover the entire amortized cost basis of the debt security,
an other-than-temporary impairment is considered to have occurred and it is measured by the present value of cash
flows expected to be collected less the amortized cost basis (credit loss). Entergy did not have any material otherthan-temporary impairments relating to credit losses on debt securities for the years ended December 31, 2014, 2013,
and 2012. The assessment of whether an investment in an equity security has suffered an other-than-temporary
impairment continues to be based on a number of factors including, first, whether Entergy has the ability and intent to
hold the investment to recover its value, the duration and severity of any losses, and, then, whether it is expected that
the investment will recover its value within a reasonable period of time. Entergy’s trusts are managed by third parties
who operate in accordance with agreements that define investment guidelines and place restrictions on the purchases
and sales of investments. Entergy did not record material charges to other income in 2014, 2013, and 2012, respectively,
resulting from the recognition of the other-than-temporary impairment of certain equity securities held in its
decommissioning trust funds.
NOTE 18. VARIABLE INTEREST ENTITIES (Entergy Corporation, Entergy Arkansas, Entergy Gulf States,
Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)
Under applicable authoritative accounting guidance, a variable interest entity (VIE) is an entity that conducts
a business or holds property that possesses any of the following characteristics: an insufficient amount of equity at risk
to finance its activities, equity owners who do not have the power to direct the significant activities of the entity (or
have voting rights that are disproportionate to their ownership interest), or where equity holders do not receive expected
losses or returns. An entity may have an interest in a VIE through ownership or other contractual rights or obligations,
and is required to consolidate a VIE if it is the VIE’s primary beneficiary. The primary beneficiary of a VIE is the
entity that has the power to direct the activities of the VIE that most significantly affect the VIE’s economic performance,
and has the obligation to absorb losses or has the right to residual returns that would potentially be significant to the
entity.
Entergy Arkansas, Entergy Gulf States Louisiana, Entergy Louisiana, and System Energy consolidate the
respective companies from which they lease nuclear fuel, usually in a sale and leaseback transaction. This is because
Entergy directs the nuclear fuel companies with respect to nuclear fuel purchases, assists the nuclear fuel companies
in obtaining financing, and, if financing cannot be arranged, the lessee (Entergy Arkansas, Entergy Gulf States Louisiana,
Entergy Louisiana, or System Energy) is responsible to repurchase nuclear fuel to allow the nuclear fuel company (the
VIE) to meet its obligations. During the term of the arrangements, none of the Entergy operating companies have been
required to provide financial support apart from their scheduled lease payments. See Note 4 to the financial statements
for details of the nuclear fuel companies’ credit facility and commercial paper borrowings and long-term debt that are
reported by Entergy, Entergy Arkansas, Entergy Gulf States Louisiana, Entergy Louisiana, and System Energy. These
amounts also represent Entergy’s and the respective Registrant Subsidiary’s maximum exposure to losses associated
with their respective interests in the nuclear fuel companies.
Entergy Gulf States Reconstruction Funding I, LLC, and Entergy Texas Restoration Funding, LLC, companies
wholly-owned and consolidated by Entergy Texas, are variable interest entities and Entergy Texas is the primary
beneficiary. In June 2007, Entergy Gulf States Reconstruction Funding issued senior secured transition bonds
(securitization bonds) to finance Entergy Texas’s Hurricane Rita reconstruction costs. In November 2009, Entergy
Texas Restoration Funding issued senior secured transition bonds (securitization bonds) to finance Entergy Texas’s
Hurricane Ike and Hurricane Gustav restoration costs. With the proceeds, the variable interest entities purchased from
Entergy Texas the transition property, which is the right to recover from customers through a transition charge amounts
sufficient to service the securitization bonds. The transition property is reflected as a regulatory asset on the consolidated
Entergy Texas balance sheet. The creditors of Entergy Texas do not have recourse to the assets or revenues of the
variable interest entities, including the transition property, and the creditors of the variable interest entities do not have
recourse to the assets or revenues of Entergy Texas. Entergy Texas has no payment obligations to the variable interest
entities except to remit transition charge collections. See Note 5 to the financial statements for additional details
regarding the securitization bonds.
229
E-5 Page 177 of 182
Entergy Corporation and Subsidiaries
Notes to Financial Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41
Entergy Arkansas Restoration Funding, LLC, a company wholly-owned and consolidated by Entergy Arkansas,
is a variable interest entity and Entergy Arkansas is the primary beneficiary. In August 2010, Entergy Arkansas
Restoration Funding issued storm cost recovery bonds to finance Entergy Arkansas’s January 2009 ice storm damage
restoration costs. With the proceeds, Entergy Arkansas Restoration Funding purchased from Entergy Arkansas the
storm recovery property, which is the right to recover from customers through a storm recovery charge amounts
sufficient to service the securitization bonds. The storm recovery property is reflected as a regulatory asset on the
consolidated Entergy Arkansas balance sheet. The creditors of Entergy Arkansas do not have recourse to the assets or
revenues of Entergy Arkansas Restoration Funding, including the storm recovery property, and the creditors of Entergy
Arkansas Restoration Funding do not have recourse to the assets or revenues of Entergy Arkansas. Entergy Arkansas
has no payment obligations to Entergy Arkansas Restoration Funding except to remit storm recovery charge collections.
See Note 5 to the financial statements for additional details regarding the storm cost recovery bonds.
Entergy Louisiana Investment Recovery Funding I, L.L.C., a company wholly-owned and consolidated by
Entergy Louisiana, is a variable interest entity and Entergy Louisiana is the primary beneficiary. In September 2011,
Entergy Louisiana Investment Recovery Funding issued investment recovery bonds to recover Entergy Louisiana’s
investment recovery costs associated with the canceled Little Gypsy repowering project. With the proceeds, Entergy
Louisiana Investment Recovery Funding purchased from Entergy Louisiana the investment recovery property, which
is the right to recover from customers through an investment recovery charge amounts sufficient to service the bonds.
The investment recovery property is reflected as a regulatory asset on the consolidated Entergy Louisiana balance
sheet. The creditors of Entergy Louisiana do not have recourse to the assets or revenues of Entergy Louisiana Investment
Recovery Funding, including the investment recovery property, and the creditors of Entergy Louisiana Investment
Recovery Funding do not have recourse to the assets or revenues of Entergy Louisiana. Entergy Louisiana has no
payment obligations to Entergy Louisiana Investment Recovery Funding except to remit investment recovery charge
collections. See Note 5 to the financial statements for additional details regarding the investment recovery bonds.
Entergy Louisiana and System Energy are also considered to each hold a variable interest in the lessors from
which they lease undivided interests in the Waterford 3 and Grand Gulf nuclear plants, respectively. Entergy Louisiana
and System Energy are the lessees under these arrangements, which are described in more detail in Note 10 to the
financial statements. Entergy Louisiana made payments on its lease, including interest, of $31.0 million in 2014, $26.3
million in 2013, and $39.1 million in 2012. System Energy made payments on its lease, including interest, of $51.6
million in 2014, $50.5 million in 2013, and $50.0 million in 2012. The lessors are banks acting in the capacity of
owner trustee for the benefit of equity investors in the transactions pursuant to trust agreements entered solely for the
purpose of facilitating the lease transactions. It is possible that Entergy Louisiana and System Energy may be considered
as the primary beneficiary of the lessors, but Entergy is unable to apply the authoritative accounting guidance with
respect to these VIEs because the lessors are not required to, and could not, provide the necessary financial information
to consolidate the lessors. Because Entergy accounts for these leasing arrangements as capital financings, however,
Entergy believes that consolidating the lessors would not materially affect the financial statements. In the unlikely
event of default under a lease, remedies available to the lessor include payment by the lessee of the fair value of the
undivided interest in the plant, payment of the present value of the basic rent payments, or payment of a predetermined
casualty value. Entergy believes, however, that the obligations recorded on the balance sheets materially represent
each company’s potential exposure to loss.
Entergy has also reviewed various lease arrangements, power purchase agreements, and other agreements in
which it holds a variable interest. In these cases, Entergy has determined that it is not the primary beneficiary of the
related VIE because it does not have the power to direct the activities of the VIE that most significantly affect the VIE’s
economic performance, or it does not have the obligation to absorb losses or the right to residual returns that would
potentially be significant to the entity, or both.
230
E-5 Page 178 of 182
Entergy Corporation and Subsidiaries
Notes to Financial
Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc.
41
NOTE 19. TRANSACTIONS WITH AFFILIATES (Entergy Arkansas, Entergy Gulf States Louisiana,
Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)
Each Registrant Subsidiary purchases electricity from or sells electricity to the other Registrant Subsidiaries,
or both, under rate schedules filed with FERC. The Registrant Subsidiaries receive management, technical, advisory,
operating, and administrative services from Entergy Services; and receive management, technical, and operating
services from Entergy Operations. These transactions are on an “at cost” basis. In addition, Entergy Power sold
electricity to Entergy Arkansas, Entergy Louisiana, and Entergy New Orleans prior to the expiration of the contract in
2013. RS Cogen sells electricity to Entergy Gulf States Louisiana.
As described in Note 1 to the financial statements, all of System Energy’s operating revenues consist of billings
to Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans.
As described in Note 4 to the financial statements, the Registrant Subsidiaries participate in Entergy’s money
pool and earn interest income from the money pool. As described in Note 2 to the financial statements, Entergy Gulf
States Louisiana and Entergy Louisiana receive preferred membership distributions from Entergy Holdings Company.
The tables below contain the various affiliate transactions of the Utility operating companies, System Energy,
and other Entergy affiliates.
Intercompany Revenues
Entergy
Arkansas
2014
2013
2012
$131.2
$349.9
$324.0
Entergy
Gulf States
Louisiana
$418.0
$383.1
$380.6
Entergy
Louisiana
Entergy
Mississippi
(In Millions)
$258.5
$169.8
$114.9
$107.3
$138.2
$36.1
Entergy
New
Orleans
$76.8
$27.0
$43.9
Entergy
Texas
System
Energy
$316.1
$369.4
$313.2
$664.4
$735.1
$622.1
Intercompany Operating Expenses
Entergy
Arkansas
2014
2013
2012
(a)
(b)
(c)
(d)
(a)
$596.6
$656.1
$580.7
Entergy
Gulf States
Louisiana
(b)
$773.1
$672.8
$532.3
Entergy
Louisiana
(c)
$490.9
$667.6
$597.4
Entergy
Mississippi
(In Millions)
$367.6
$399.0
$352.7
Entergy
New
Orleans
(d)
$241.5
$279.6
$247.2
Entergy
Texas
System
Energy
$445.3
$418.1
$386.1
$156.7
$175.2
$147.4
Includes power purchased from Entergy Power of $3.3 million in 2013 and $1.4 million in 2012. The contract
with Entergy Power expired in May 2013.
Includes power purchased from RS Cogen of $3.2 million in 2013 and $2.8 million in 2012.
Includes power purchased from Entergy Power of $8.1 million in 2013 and $14.3 million in 2012. The contract
with Entergy Power expired in May 2013.
Includes power purchased from Entergy Power of $8 million in 2013 and $14.1 million in 2012. The contract
with Entergy Power expired in May 2013.
231
E-5 Page 179 of 182
Entergy Corporation and Subsidiaries
Notes to Financial Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41
Intercompany Interest and Investment Income
Entergy
Arkansas
2014
2013
2012
$—
$—
$—
Entergy
Gulf States
Louisiana
Entergy
Louisiana
Entergy
Mississippi
(In Millions)
$87.6
$—
$78.2
$—
$78.2
$—
$30.3
$27.5
$28.2
Entergy
New
Orleans
$—
$—
$—
Entergy
Texas
System
Energy
$—
$—
$0.1
$—
$—
$—
NOTE 20. QUARTERLY FINANCIAL DATA (UNAUDITED) (Entergy Corporation, Entergy Arkansas,
Entergy Gulf States Louisiana, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas,
and System Energy)
Operating results for the four quarters of 2014 and 2013 for Entergy Corporation and subsidiaries were:
Operating
Revenues
2014:
First Quarter
Second Quarter
Third Quarter
Fourth Quarter
2013:
First Quarter
Second Quarter
Third Quarter
Fourth Quarter
Operating
Consolidated
Income
Net Income
(In Thousands)
Net Income
Attributable to
Entergy
Corporation
$3,208,843
$2,996,650
$3,458,110
$2,831,318
$739,877
$454,477
$492,859
$319,674
$406,053
$194,281
$234,916
$125,006
$401,174
$189,383
$230,037
$120,127
$2,608,874
$2,738,208
$3,351,959
$2,691,906
$394,045
$346,512
$388,894
$225,548
$166,982
$168,055
$244,182
$151,353
$161,400
$163,723
$239,850
$146,929
Earnings per Average Common Share
2014
First Quarter
Second Quarter
Third Quarter
Fourth Quarter
Basic
$2.24
$1.06
$1.28
$0.67
2013
Diluted
$2.24
$1.05
$1.27
$0.66
Basic
$0.91
$0.92
$1.35
$0.82
Diluted
$0.90
$0.92
$1.34
$0.82
As discussed in more detail in Note 1 to the financial statements, operating results for 2014 include $154
million ($100 million after-tax) of charges related to Vermont Yankee primarily resulting from the effects of an updated
decommissioning cost study completed in the third quarter 2014 along with reassessment of assumptions regarding
the timing of decommissioning cash flows and severance and employee retention costs. Results of operations for 2014
also include the $56.2 million ($36.7 million after-tax) write-off of Entergy Mississippi’s regulatory asset associated
with new nuclear generation development costs as a result of a joint stipulation entered into with the Mississippi Public
Utilities Staff, subsequently approved by the MPSC, in which Entergy Mississippi agreed not to pursue recovery of
232
E-5 Page 180 of 182
Entergy Corporation and Subsidiaries
Notes to Financial
Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc.
41
the costs deferred by an MPSC order in the new nuclear generation docket. See Note 2 to the financial statements for
further discussion of the new nuclear generation development costs and the joint stipulation.
Results of operations for 2013 include $322 million ($202 million after-tax) of impairment and other related
charges primarily to write down the carrying value of Vermont Yankee and related assets to their fair values. See Note
1 to the financial statements for further discussion of the charges. Also, as discussed in more detail in Note 13 to the
financial statements, operating results include approximately $110 million ($70 million after-tax) in costs in 2013
associated with the human capital management strategic imperative, primarily implementation costs, severance
expenses, pension curtailment losses, and special termination benefits expense. In December 2013, Entergy deferred
for future recovery approximately $45 million ($30 million after-tax) of these costs in the Arkansas and Louisiana
jurisdictions, as approved by the APSC and the LPSC, respectively.
The business of the Utility operating companies is subject to seasonal fluctuations with the peak periods
occurring during the third quarter. Operating results for the Registrant Subsidiaries for the four quarters of 2014 and
2013 were:
Operating Revenues
2014:
First Quarter
Second Quarter
Third Quarter
Fourth Quarter
2013:
First Quarter
Second Quarter
Third Quarter
Fourth Quarter
Entergy
Arkansas
Entergy
Gulf States
Louisiana
Entergy
Louisiana
$514,981
$511,522
$627,153
$518,735
$513,295
$554,034
$610,493
$473,104
$623,494
$736,408
$870,181
$595,798
$348,196
$370,638
$425,341
$380,018
$542,392
$508,653
$647,671
$491,443
$419,955
$492,361
$558,331
$470,486
$606,085
$635,805
$782,789
$602,256
$291,641
$326,039
$397,833
$319,027
Entergy
Entergy
Mississippi New Orleans
(In Thousands)
Entergy
Texas
System
Energy
$186,567
$169,989
$182,971
$150,558
$440,256
$482,932
$528,508
$400,286
$157,667
$163,830
$172,151
$170,716
$146,466
$142,841
$178,641
$152,208
$306,173
$455,100
$526,978
$440,548
$168,578
$172,177
$192,679
$201,655
Operating Income (Loss)
2014:
First Quarter
Second Quarter
Third Quarter
Fourth Quarter
2013:
First Quarter
Second Quarter
Third Quarter
Fourth Quarter
Entergy
Arkansas
Entergy
Gulf States
Louisiana
Entergy
Louisiana
$66,360
$68,970
$115,357
$19,317
$82,576
$70,350
$96,698
$43,766
$85,057
$100,176
$160,595
$38,615
$57,132
$59,063
$9,403
$61,162
$43,314
$80,942
$157,681
$23,123
$52,083
$53,856
$85,284
$56,114
$64,728
$88,691
$145,847
$56,128
$37,123
$46,809
$70,186
$36,112
Entergy
Mississippi
(In Thousands)
233
Entergy
New Orleans
Entergy
Texas
System
Energy
$15,281
$12,862
$24,866
($539)
$43,056
$53,158
$82,911
$29,590
$52,029
$56,547
$58,484
$54,056
$4,272
$3,627
$15,895
$3,070
$26,277
$38,355
$79,430
$30,071
$52,052
$51,632
$52,029
$47,367
E-5 Page 181 of 182
Entergy Corporation and Subsidiaries
Notes to Financial Statements
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41
Net Income (Loss)
2014:
First Quarter
Second Quarter
Third Quarter
Fourth Quarter
2013:
First Quarter
Second Quarter
Third Quarter
Fourth Quarter
Entergy
Arkansas
Entergy
Gulf States
Louisiana
Entergy
Louisiana
Entergy
Mississippi
(In Thousands)
Entergy
New Orleans
Entergy
Texas
System
Energy
$28,370
$29,005
$62,980
$1,037
$46,472
$36,171
$55,535
$24,313
$58,378
$69,667
$123,821
$31,665
$25,839
$26,564
($6,464)
$28,882
$8,294
$6,374
$13,932
$107
$13,165
$18,585
$39,559
$3,495
$24,619
$25,931
$26,730
$19,054
$14,719
$40,483
$82,577
$24,169
$27,165
$29,720
$62,642
$42,135
$45,376
$61,377
$100,597
$45,114
$13,934
$18,954
$33,813
$15,458
$1,307
$598
$8,086
$1,692
$922
$10,953
$35,801
$10,205
$28,006
$27,734
$35,105
$22,819
Earnings (Loss) Applicable to Common Equity
Entergy
Arkansas
2014:
First Quarter
Second Quarter
Third Quarter
Fourth Quarter
2013:
First Quarter
Second Quarter
Third Quarter
Fourth Quarter
Entergy
Gulf States
Louisiana
Entergy
Entergy
Louisiana Mississippi
(In Thousands)
Entergy
New Orleans
$26,652
$27,287
$61,262
($682)
$46,266
$35,962
$55,329
$24,107
$56,640
$67,910
$122,083
$29,929
$25,132
$25,857
($7,171)
$28,175
$8,053
$6,133
$13,691
($135)
$13,001
$38,765
$80,859
$22,450
$26,959
$29,514
$62,436
$41,928
$43,638
$59,639
$98,859
$43,378
$13,227
$18,247
$33,106
$14,751
$1,066
$357
$7,845
$1,450
234
E-5 Page 182 of 182
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41
Schedule E-6
Standard Journal Entries
Partially Projected Test Year Ended
March 31, 2015
Arkansas Public Service Commission
Minimum Filing Requirements
Entergy Arkansas, Inc.
Docket No. 15-015-U
(1)
Ln
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44
(2)
Standard
Journal
Entry
106
ACC
ACF
ACU
ADD
ADJ
AFC
AFD
ALI
ALO
AMB
AME
AMJ
AMP
AMS
AP1
AP2
AP4
AP5
AP6
APA
APB
APD
APE
APF
APG
APM
APQ
APR
APS
APV
APX
ARC
ARM
ARN
ARO
ARS
ART
ATS
ATX
AVR
AWP
BAC
BIB
(3)
Journal Entry Description
Non-unitized Closed
AP Closed Vouchers
Benefits Accruals
Accrued Unbilled Revenue
Unitized Additions
Charge Adjustment
AFUDC Corrections
AFUDC Calculation
INTERDEPT. RENTS & SALES
EPM Allocations
Prepaid Amortizations
Nuclear Fuel
AMORT. PROP. UNDER FIN.
Prepaid Amortizations -Postage
WF3 AMORTIZATION
Accounts Payable Detail Jrnl
AP Payment Journal
Dynamic Discount Adjustment
PeopleSoft AP Cash Reclass
AP5 Reclass Operating Bus/234011
Monthly AP Accruals
AP System Accrual - ETR
Invoice True-up Distribution
PCARD Detail Charges
AP RECLASS - MISC
AP Accruals in PS GL
AP Miscellaneous Corrections
Monthly AP Accrual Reversal
Sabrix - ARK Rebates & Credits
AP Dist - Tax Accrual - Sabrix
AP Journal Voucher
AP Cancelled Payments
ARM Corrections
AR Maintenance
Non System AR Corrections
ARO
AR Payments
Automatic Retirements
Manual Corr AP Tax - Sabrix
AP Tax Accruals
ARK Vendor-Billed-Tax Rebate
CWIP/RWIP Allocation
BI Accrue Unbilled Revenue
BI Billing
E-6 Page 1 of 5
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41
Schedule E-6
Standard Journal Entries
Partially Projected Test Year Ended
March 31, 2015
Arkansas Public Service Commission
Minimum Filing Requirements
Entergy Arkansas, Inc.
Docket No. 15-015-U
(1)
Ln
45
46
47
48
49
50
51
52
53
54
55
56
57
58
59
60
61
62
63
64
65
66
67
68
69
70
71
72
73
74
75
76
77
78
79
80
81
82
83
84
85
86
87
88
(2)
Standard
Journal
Entry
BLA
BLA
BLP
CAJ
CAR
CDR
CIA
CLC
CMA
CNS
COB
COE
COF
COF
COG
COJ
CS1
CS2
CS3
CSA
CSH
DEB
DEC
DEF
DFA
DFA
DFB
DGL
DPR
EMA
EPU
EQY
ERD
ESC
ESG
ESR
EXE
EXP
EXT
FLA
FLB
FLB
FLC
FLP
(3)
Journal Entry Description
BLUK PWR - ACTUALS
Nuclear Fuel
Cost of Serv Intercompany Rev
Co-owner Misc Corrections
Contracts Revenue
Contracts Deferred Revenue
Co-owner Aper Costs Oth
Coal Costs
Corp Monthly Accruals
Eliminations
LA Generating Co-owner Billing
Rec of Injury&Damages-Qrtly
Co-own Alloc Fuel-Pr Mnth Rev
Co-Owner Allocation of Fuel
Co-own Alloc Fuel-Pr Mnth Rev
AECC Monthly Billing
CCS/CIS Distribution/Retail Activity-Dollars
CCS/CIS Revenue Distribution-Usage
CCS/CIS Distribution/Retail Activity-Stats
CIS/CCS Corrections & Adj
CASH RECEIPTS
Amrt Loss,PRM&Exp on FMB & PCB
Nuclear Decommissioning Serv
DIVIDENDS DECLARED
Deferred Fuel Costs
Nuclear Fuel
GG1 Settlement
Debt Gain/Loss
Depreciation
MISC. ACCR. - NORTHEAST PLANTS
PeopleSoft EPM
GSU Subs
Accrued Unbilled Revenue
ESI BILL CORRECTIONS
ESI General Journals
ESI Reclass
Outside Stock Awards
EXPENSES - NON-REG
EXTERNAL RECLASS (ADJ PERIOD)
Nuclear Fuel
GAS COSTS-ACTUAL PRIOR MO
Spindletop Gas Storage
Gas & Oil Costs-Gas
GAS COSTS-ACTUAL PRIOR MO
E-6 Page 2 of 5
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41
Schedule E-6
Standard Journal Entries
Partially Projected Test Year Ended
March 31, 2015
Arkansas Public Service Commission
Minimum Filing Requirements
Entergy Arkansas, Inc.
Docket No. 15-015-U
(1)
Ln
(2)
Standard
Journal
Entry
89
90
91
92
93
94
95
96
97
98
99
100
101
102
103
104
105
106
107
108
109
110
111
112
113
114
115
116
117
118
119
120
121
122
123
124
125
126
127
128
129
130
131
132
GEN
HOU
INE
INH
ISB
ISE
ISP
LEC
LEP
LGA
LOB
MCB
MCI
MCR
MIS
MIT
MPI
MPL
MPR
MS2
MSA
MSC
MSS
NID
NRR
OIL
OHA
OHB
OHR
OSA
OSB
OSC
OSR
OVD
PAA
PAC
PAJ
PAL
PAV
PCC
PIT
PPA
PPB
PPD
(3)
Journal Entry Description
MISC. GEN JOURNAL
NON-REG - EAM
Customer Deposit Interest
Decommissioning Trust Int Inc.
Fossil Fuel Statistics PM Act
Income Statement Eliminations
Fossil Fuel Statistics PM Act
Lease Correction - PwrPlt
Lease Payment - PwrPlt
Interco Loan/Guaranty Accruals
Equitization Processing
Assets/Liab@PEND Rate
Income Statement @ AVG Rate
Revalue Balance Sheet
MISC CORR FOR NUC
MISC. INTEREST INCOME
INTEREST INCOME/EXPENSE
MONEY POOL
RECLASS MONEY POOL BALANCES
M&S DISTRIBUTION - PASSPORT
M&S Corrections
M&S Corrections
M&S Dist - Tax Accrual -Sabrix
Nuclear Interest Donation
Non Regulated Reclass
Entergy System Oil
HCL Billing Accrual
HCL Outsource Billing
HCL Outsruce Accrual - Reversal
SAIC Billing Accrual -EPM
OUTSOURCE BILLING
OUT SOURCE BILLING-CUSH&WAKEFD
SAIC Bill Accrual- Reversal
Allocated Overheads
Depreciation Expense
ASSET MANAGEMENT ADJ
PowerPlant Allocations
Misc Asset Correction Journal
To Record Capital Leases
Misc CWIP Correction Journal
Property Interest Inc/Expense
Sale for Resale/Purchase Power
Grand Gulf Purchase Power
Sale for Resale/Purchase Power
E-6 Page 3 of 5
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41
Schedule E-6
Standard Journal Entries
Partially Projected Test Year Ended
March 31, 2015
Arkansas Public Service Commission
Minimum Filing Requirements
Entergy Arkansas, Inc.
Docket No. 15-015-U
(1)
Ln
(2)
Standard
Journal
Entry
133
134
135
136
137
138
139
140
141
142
143
144
145
146
147
148
149
150
151
152
153
154
155
156
157
158
159
160
161
162
163
164
165
166
167
168
169
170
171
172
173
174
175
176
PPM
PR1
PR2
PR3
PR4
PR5
PR6
PR8
PRA
PRB
PRC
PRU
PRV
PTR
PTU
QMA
RCC
RCL
REF
REG
REN
RES
RET
RTR
SAC
SAR
SCR
SEA
ST1
ST2
ST3
ST4
STA
STD
STR
TKS
TM3
TMC
TMJ
TPA
TPM
TPO
TPR
TPV
(3)
Journal Entry Description
MISO Trans Revnue & Exp Settl
PAYROLL DISTRIBUTION
INCENTIVE ACCRUAL
PR BENEFITS ALLOCATION
PR TAX ALLOCATIONS
NON PRODUCTIVE LOADING
PR ACCRUAL REVERSAL
PAYROLL ACCRUAL
PAYROLL CORRECTIONS
PAYROLL CORR - NEW ORLEANS
PAYROLL DEDUCTIONS
Payroll Corr excluded from SCR
Accrued Vacation Rollover
Work Order Journal Entries
Project Transfer Non Billing
QUARTERLY MISC. ACCRUALS
Cash Flow Reclass
Accumulated Provision Reclass
SERI FERC SETTLE 1994
Regulatory Assets & Liabilitie
REVENUE - NON-REG
RESERVES
Retirements
Reserve Transfers
Storm Accrual - EPM
Storm Accrual Reversal - EPM
Mixed Service Cost (Results)
SERI Sales Leaseback
Storm Damage Alloc 1
Storm Alloc 2
Storm Alloc 3
Storm Alloc 4
Storm Damage Adjustment
Storm Damage
STORM RECLASS FR PWR PLT
Truck Stock Alloc (Capital)
Clear Check Money Pool Acct.
Treasury Cash Accounting Lines
Treasury Journal
Audit Adjustment - Tax Prov
Amended Adjust - Tax Provision
Other Adjustments - Tax Prov
RTA - Tax Provision
Monthly Tax Provision
E-6 Page 4 of 5
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41
Schedule E-6
Standard Journal Entries
Partially Projected Test Year Ended
March 31, 2015
Arkansas Public Service Commission
Minimum Filing Requirements
Entergy Arkansas, Inc.
Docket No. 15-015-U
(1)
Ln
(2)
Standard
Journal
Entry
177
178
179
180
181
182
183
TRF
TSK
TXA
TXC
TXE
TXF
TXG
(3)
Journal Entry Description
Asset Transfers
Truck Stock Alloc (O&M)
INCOME TAXES
CORPORATE FRANCHISE TAX ACCRU
CURRENT/DEFERRED TAX
TAXES OTHER THAN INC TAXES
FRANCHISE TAX
E-6 Page 5 of 5
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41 Schedule E-9
Arkansas Public Service Commission
Chart of Accounts
Minimum Filing Requirements
Partially Projected Test Year Ended
Entergy Arkansas, Inc.
March 31, 2015
Docket No. 15-015-U
(1)
LN
(2)
Account
(3)
Account Title
1
Assets and Other Debits
2
Utility Plant
(4)
Account Description
3
101000
Plant In Service
This is a manual account for plant-in-service transactions which
are NOT incorporated in the Property Accounting Sub-ledger
through Power Plant software. Plant-in-service transactions which
are incorporated in the Property Accounting Sub-legder through
PowerPlant are included in gl acct 1010AM.
4
101060
Asset Retirement Obligat Asset
This account includes the cost of electric plant representing the
fair value of retirement obligations for tangible, long-lived assets .
5
101061
ARO Asset-Fossil Steam Product
6
101062
ARO Assett - Hydro Production
7
101063
ARO Asset - Other Production
8
1010AM
Electric Plant In Service
This account includes the cost of electric steam plant representing
the fair value of retirement obligations for tangible, long-lived
assets .
This account includes the cost of electric hydro plant representing
the fair value of retirement obligations for tangible, long-lived
assets .
This account includes the cost of electric other plant representing
the fair value of retirement obligations for tangible, long-lived
assets .
This account shall include the original cost of electric plant,
included in accounts 301 to 399, prescribed herein, owned and
used by the utility in its electric utility operations, and having an
expectation of life in service of more than one year from date of
installation, including such property owned by the utility but held
by nominees. (See also account 106 for unclassified construction
costs of completed plant actually in service.)
9
1010IS
Contra Asset-EAI Sec Ice Storm
10
101100
Property Under Capital Lease
11
1011LR
Capital Lease Amortization
12
1011LS
Property under Capital Lease
13
101X09
Const. Elec.-Cash Flow Reclass
Accounts ending in "X06", "X07, "X08", and "X09" were created for
the sole purpose of being able to journalize certain cash flow
statement reclassifications into the general ledger. These
accounts do not contain any original operational transactions.
They are simply used to modify cash flow statement line item
presentations in our internally generated cash flow statements.
14
102000
Plant Purchased Or Sold
15
1050AM
Plant Held For Future Use
This account shall be charged with the cost of electric plant
acquired as an operating unit or system by purchase, merger,
consolidation liquidation, or otherwise, and shall be credited with
the selling price of like property transferred to others pending the
distribution to appropriate accounts in accordance with USOA
electric plant instruction 5.
This account shall include the original cost of electric plant (except
land and land rights) owned and held for future use in electric
service under a definite plan for such use, to include: (1) Property
acquired (except land and land rights) but never used by the utility
in electric service, but held for such service in the future under a
definite plan, and (2) property (except land and land rights)
previously used by the utility in service, but retired from such
service and held pending its reuse in the future, under a definite
plan, in electric service.
This account represents the securitization bonds issued for storm
restoration costs incurred.
This account shall include the amount recorded under capital
leases for plant leased from others and used by the utility in its
utility operations.
This account contains the accumulated provision for amortization
of plant leased assets.
This account contains the cost of plant assets leased from others.
E-9 Page 1 of 99
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41 Schedule E-9
Arkansas Public Service Commission
Chart of Accounts
Minimum Filing Requirements
Partially Projected Test Year Ended
Entergy Arkansas, Inc.
March 31, 2015
Docket No. 15-015-U
(1)
LN
(2)
Account
(3)
Account Title
(4)
Account Description
16
106000
Completed Projcts Unclassified
At the end of the year or such other date as a balance sheet may
be required by the Commission, this account shall include the total
of the balances of work orders for electric plant which has been
completed and placed in service but which work orders have not
been classified for transfer to the detailed electric plant accounts.
17
107000
Constr. Work In Progress
18
107POL
CWIP-Storm Adder Poles
19
108000
Accum Prov Depr Plnt Service
20
1080AM
Accum Prov Depr Plant Service
21
1080IS
Accu Prov Contra PIS EAI Secur
22
108100
Accumulated Depr - Aro Assets
23
108101
A/D - Steam Production Plnt
24
108102
A/D - Nuclear Production Plnt
25
108104
A/D - Other Production Plant
26
108105
A/D - Transmission Plant
27
108106
A/D - Distribution Plant
28
108107
A/D - General Plant
29
108110
AccumDeprec-ARO Asset-Fossil S
30
108111
Accum Deprec ARO Asset - Hydro
31
108112
Accum Deprec-ARO Asset-Other
32
108151
Insurance proceeds-CAP-Ele
33
34
108210
108220
Original Cost
Rwip - Removal Cost
35
108230
Rwip - Salvage - Scrap
36
108250
Rwip - Salvage - Other
This account includes the total of the balances of work orders for
electric plant in process of construction.
This account contains the cost of construction work in progress for
Storm poles.
To record depreciation prior to business unit being transferred
from Houston's PeopleSoft to Entergy's PeopleSoft.
This account contains the accumulated provision for depreciation
of electric utility plant.
This account contains the accumulated provision for depreciation
of storm restoration costs.
This account contains the accumulated provision for depreciation
of ARO asset.
This account records certain reserve adjustments with Ad HOC
approval from the PSC since 1995. PowerPlant does not
currently have the functionality to effect these monthly Reserve
Transfers.
This account records certain reserve adjustments with Ad HOC
approval from the PSC since 1995. PowerPlant does not
currently have the functionality to effect these monthly Reserve
Transfers.
To record the accumulated depreciation related to the INDUS
computer software leased to EEI/Nuclear.
This account records certain reserve adjustments with Ad HOC
approval from the PSC since 1995. PowerPlant does not
currently have the functionality to effect these monthly Reserve
Transfers.
These accounts records monthly reserve adjustments with Ad
HOC approval from the PSC since 1995. But PowerPlant does
not currently have the functionality to effect these monthly
Reserve Transfers. The Reserve Adjustments are redundant
from June 1, 2009, based on the settlement with CNO (Docket UD08-03.
These accounts records monthly reserve adjustments with Ad
HOC approval from the PSC since 1995. But PowerPlant does
not currently have the functionality to effect these monthly
Reserve Transfers. The Reserve Adjustments are redundant
from June 1, 2009, based on the settlement with CNO (Docket UD08-03.
This account contains the accumulated provision for depreciation
of ARO fossil assets.
This account contains the accumulated provision for depreciation
of ARO hydro assets.
This account contains the accumulated provision for depreciation
of ARO other plant assets.
This account contains the insurance proceeds recoverable on
plant assets to be retired.
The account represents the closings to plant from CWIP.
This account contains the cost of removal charges incurred on
plant assets to be retired.
This account contains the salvage value on plant assets to be
retired.
The account includes construction charges for the disposition of
salvage material.
E-9 Page 2 of 99
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41 Schedule E-9
Arkansas Public Service Commission
Chart of Accounts
Minimum Filing Requirements
Partially Projected Test Year Ended
Entergy Arkansas, Inc.
March 31, 2015
Docket No. 15-015-U
(1)
LN
(2)
Account
(3)
Account Title
(4)
Account Description
37
108260
AccDep-Removal-Fossil-Contra
This account contains the accumulated provision for depreciation
related to the COR component that is reclassified to a regulatory
asset or regulatory liability for SEC reporting.
38
108261
AccDep-Removal-Hydro-Contra
This account contains the accumulated provision for depreciation
related to the COR component that is reclassified to a regulatory
asset or regulatory liability for SEC reporting.
39
108262
AccDep-Removal-Other-Contra
This account contains the accumulated provision for depreciation
related to the COR component that is reclassified to a regulatory
asset or regulatory liability for SEC reporting.
40
1082AM
Cost of Removal - Accrual
This account contains the accumulated provision for depreciation
related to the COR component that is reclassified to a regulatory
asset or regulatory liability for SEC reporting.
41
1082IS
Accu Cost Rmvl Contra EAI Secu
42
108X01
Reclass 108220 fr. Accum. Dep
43
108X02
Reclass 108220 to Reg. Asset
44
108X08
Ins proceeds-capital-CF Reclas
This account contains the accumulated provision for depreciation
related to storm charges.
Accounts ending in "X01", "X02", "X03", and "X04" were created
for the sole purpose of being able to journalize certain balance
sheet statement reclassifications into the general ledger. These
accounts do not contain any original operational transactions.
They are simply used to modify the balance sheet statement line
item presentations in our internally generated balance sheet
statements.
Accounts ending in "X01", "X02", "X03", and "X04" were created
for the sole purpose of being able to journalize certain balance
sheet statement reclassifications into the general ledger. These
accounts do not contain any original operational transactions.
They are simply used to modify the balance sheet statement line
item presentations in our internally generated balance sheet
statements.
Accounts ending in "X06", "X07, "X08", and "X09" were created for
the sole purpose of being able to journalize certain cash flow
statement reclassifications into the general ledger. These
accounts do not contain any original operational transactions.
They are simply used to modify cash flow statement line item
presentations in our internally generated cash flow statements.
45
108X09
Retirement Elec.-Cash Flow Rec
Accounts ending in "X06", "X07, "X08", and "X09" were created for
the sole purpose of being able to journalize certain cash flow
statement reclassifications into the general ledger. These
accounts do not contain any original operational transactions.
They are simply used to modify cash flow statement line item
presentations in our internally generated cash flow statements.
46
111000
Acc Prov Amort Elec Util Plnt
This account normally records accum amort of Intangibles,
recorded manually.
E-9 Page 3 of 99
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41 Schedule E-9
Arkansas Public Service Commission
Chart of Accounts
Minimum Filing Requirements
Partially Projected Test Year Ended
Entergy Arkansas, Inc.
March 31, 2015
Docket No. 15-015-U
(1)
LN
(2)
Account
(3)
Account Title
(4)
Account Description
47
1110AM
Accum Prov Amort Elec Util Pln
This account shall be credited with 1) amounts charged to account
404, Amortization of Limited-Term Electric Plant, for the current
amortization of limited-term electric plant investments, 2) amounts
charged to account 421, Miscellaneous Nonoperating Income, for
amortization expense on property included in account 105,
Electric Plant Held for Future Use, 3) Amounts charged to account
405, Amortization of Other Electric Plant, 4) Amounts charged to
account 413, Expenses of Electric Plant Leased to Others, for the
current amortization of limited-term or other investments subject
to amortization included in account 104, Electric Plant Leased to
Others, 5) amounts charged to account 425, Miscellaneous
Amortization, for the amortization of intangible or other electric
plant which does not have a definite or terminable life and is not
subject to charges for depreciation expense, with Commission
approval.
48
114000
Acq-Hot Spring Plant
49
114X01
PAA reclass to Util Plt (Cr)
This account shall include the difference between (1) the cost to
the accounting utility of electric plant acquired as an operating unit
or system by purchase, merger, consolidation, liquidation, or
otherwise, and (2) the original cost, estimated, if not known, of
such property, less the amount or amounts credited by the
accounting utility at the time of acquisition to accumulated
provisions for depreciation and amortization and contributions in
aid of construction with respect to such property, as pertaining to
the Hot Spring CCGT.
To accomplish an SEC reporting (10Q/10K) balance sheet
reclassification from Accumulated Depreciation to Electric Utility
Plant related to negative plant acquisition adjustments (PAA).
50
114X02
PAA reclass to AccDepr (Dr)
To accomplish an SEC reporting (10Q/10K) balance sheet
reclassification from Accumulated Depreciation to Electric Utility
Plant related to negative plant acquisition adjustments (PAA).
51
115000
Accum Prov-Hot Spring Plant
This account shall be credited or debited with amounts which are
includible in account 406. Amortization of Electric Plant Acquisition
Adjustments or account 425, Miscellaneous Amortization, for the
purpose of providing for the extinguishment of amounts in account
114, Electric Plant Acquisition Adjustments, in instances where
the amortization of account 114 is not being made by direct writeoff of the account, pertaining to the Hot Spring CCGT.
52
118001
Construction In Progress
53
119220
Rwip Removal Cost
54
120100
Nuclear Fuel
55
12017P
Nuclear Fuel-Unpledged (CPD)
56
12017R
Nuclear Fuel-Unpledged (CRD)
57
120510
Spent Fuel Dry Strg Casts Amor
This account shall include the total of the balances of work orders
for Gas plant in process of construction.
This account shall include the total of the balances of work orders
for Removal Cost of Projects.
This account shall include the original cost to the utility of nuclear
fuel materials while in process of refinement, conversion,
enrichment, and fabrication into nuclear fuel assemblies and
components, including processing, fabrication, and necessary
shipping costs.
Account records the purchase of nuclear fuel through a cash
transaction and not through an accrual. Capturing nuclear fuel
cash paid activity in a separate 120.1 subaccount is needed to
facilitate presentation on the cash flow statement.
Account records the sale of nuclear fuel through a cash
transaction and not through an accrual. Capturing nuclear fuel
cash received activity in a separate 120.1 subaccount is needed
to facilitate presentation on the cash flow statement.
This account is used to capture the costs of spent fuel dry storage
casks as part of the fuel costs.
E-9 Page 4 of 99
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41 Schedule E-9
Arkansas Public Service Commission
Chart of Accounts
Minimum Filing Requirements
Partially Projected Test Year Ended
Entergy Arkansas, Inc.
March 31, 2015
Docket No. 15-015-U
(1)
LN
(2)
Account
(3)
Account Title
58
120600
Nuclear Fuel-Capital Leases
59
1206CP
N.F. Cap. Leases (CPD)
60
120X08
Nuclear Fuel Purch-CF Reclass
61
(4)
Account Description
This account shall include the amount recorded under capital
leases for nuclear fuel leased from others for use by the utility in
its utility operations.
The 1206, 227, and 243205 accounts capture the nuclear fuel
under lease. The balance in this account is offset by the sum of
the non-current and current payable to River Fuel Trust. Account
records the purchase of nuclear fuel under lease through a cash
transaction and not through an accrual. Capturing nuclear fuel
under lease cash paid activity in a separate 120.6 subaccount is
needed to facilitate presentation on the cash flow statement.
Accounts ending in "X06", "X07, "X08", and "X09" were created for
the sole purpose of being able to journalize certain cash flow
statement reclassifications into the general ledger. These
accounts do not contain any original operational transactions.
They are simply used to modify cash flow statement line item
presentations in our internally generated cash flow statements.
Other Property and Investments
62
63
121000
1210AM
Nonutility Property
Non Utility Property
To record property not used in utility service.
This account shall include the book cost of land, structures,
equipment, or other tangible or intangible property owned by the
utility, but not used in utility service and not properly includible in
account 105, Electric Plant Held for Future Use. This account shall
also include, where applicable, amounts recorded for asset
retirement costs associated with nonutility plant.
64
122000
Acc Prv Depr Amrt Nonutl Prp
This account shall include the accumulated provision for
depreciation and amortization applicable to nonutility property.
65
1220AM
Acc Prv Depr Amrt Nonutl Prop
This account shall include the accumulated provision for
depreciation and amortization applicable to nonutility property.
66
123100
Investment In Subsidiary -Equi
This account shall include the cost of investments in securities
issued or assumed by subsidiary companies and investment
advances to such companies, including interest accrued thereon
when such interest is not subject to current settlement plus the
equity in undistributed earnings or losses of such subsidiary
companies since acquisition. This account shall be credited with
any dividends declared by such subsidiaries.
67
123101
Inv.Assoc.Cos-Arklahoma-Inv.
Represents Entergy Arkansas' 47.6% ownership share of
unappropriated retained earnings of The Arklahoma Corporation.
The Arklahoma Corp was formed jointly by Entergy Arkansas,
Oklahoma Gas & Electric Company and Southwestern Electric
Power Company in 1947. Arklahoma owns certain facilities
consisting of a 161 KV transmission line extending 166 miles from
Lake Catherine, AR to Boudinot Tap, near Tahlequah, OK. The
facilities are jointly leased and operated by EAI, OG&E and
SWEPCO. Equity earnings are recorded annually in December for
the previous fiscal year ended in November.
68
123104
System Fuel,Inc.- Notes Rec
The account records Entergy Arkansas note receivable
investment in its subsidiary System Fuels.
E-9 Page 5 of 99
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41 Schedule E-9
Arkansas Public Service Commission
Chart of Accounts
Minimum Filing Requirements
Partially Projected Test Year Ended
Entergy Arkansas, Inc.
March 31, 2015
Docket No. 15-015-U
(1)
LN
(2)
Account
(3)
Account Title
(4)
Account Description
69
123105
Invassoc Cos Arklaho Eqty Ear
Represents Entergy Arkansas' 47.6% ownership share of
unappropriated retained earnings of The Arklahoma Corporation.
The Arklahoma Corp was formed jointly by Entergy Arkansas,
Oklahoma Gas & Electric Company and Southwestern Electric
Power Company in 1947. Arklahoma owns certain facilities
consisting of a 161 KV transmission line extending 166 miles from
Lake Catherine, AR to Boudinot Tap, near Tahlequah, OK. The
facilities are jointly leased and operated by EAI, OG&E and
SWEPCO. Equity earnings are recorded annually in December for
the previous fiscal year ended in November.
70
123189
Dividends Rec'd-Consol Affil.
71
123196
Inv in Sub - Noncash
72
123199
Investment in Sub - Capital
73
123DIP
Affiliate Note rec-bankruptcy
74
124102
Capitol Avenue Development Co
75
124X07
Other Invest-DrCashFlowReclass
Account records the reduction in a parent companies' investment
in its subsidiary as a result of receiving a dividend distribution from
such subsidiary.
Record noncash investmnt in subsidry transactns result from
mergers/ownrshp transfrs in order to facilitate auto of cash flow
statemnt. Start captring noncash transactns that record to acct
123199 in the past.
This account records Entergy Arkansas' capital investment in its
subsidiaries.
To record the note between ENOI and affiliates for claims held in
bankruptcy.
Entergy Arkansas’ interest in Capital Avenue Development
Company (a limited partnership engaged in the business of
constructing, owing, maintaining, operating and leasing a 40-story
commercial office building).
Accounts ending in "X06", "X07, "X08", and "X09" were created for
the sole purpose of being able to journalize certain cash flow
statement reclassifications into the general ledger. These
accounts do not contain any original operational transactions.
They are simply used to modify cash flow statement line item
presentations in our internally generated cash flow statements.
76
124X08
Other Invest-CrCashFlowReclass
Accounts ending in "X06", "X07, "X08", and "X09" were created for
the sole purpose of being able to journalize certain cash flow
statement reclassifications into the general ledger. These
accounts do not contain any original operational transactions.
They are simply used to modify cash flow statement line item
presentations in our internally generated cash flow statements.
77
128001
Nuc Decom Val Act-Nqf-Sfas 115
78
128003
Nuc Decom Val Acct-Qf-Sfas 115
79
128004
Nuc Decom Act-Ano2-Qf-Sfas 115
Account used to record changes in the unrealized appreciation
and depreciation of nonqualified assets.
Account used to record changes in the unrealized appreciation
and depreciation of qualified assets.
Account used to record changes in the unrealized appreciation
and depreciation of qualified assets for EAI Unit 2.
80
128104
Decommission Trust Fund-Qual
81
128106
Decomm Trust Fund Non Qual
82
128400
Escrow Funds - Sun Trust Bank
Account to record EAI's nuclear decommissioning valuation as per
SFAS 115 for qualified funds.
Account to record EAI's nuclear decommissioning valuation as per
SFAS 115 for non-qualified funds.
Account to record escrow funds related to the acquisition of Hinds
and Hot Spring plants. The Escrow Fund shall secure the
indemnification obligatoins of Seller with respect to any amounts
payable pursuant to Article IX of the Purchase Agreement.
E-9 Page 6 of 99
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41 Schedule E-9
Arkansas Public Service Commission
Chart of Accounts
Minimum Filing Requirements
Partially Projected Test Year Ended
Entergy Arkansas, Inc.
March 31, 2015
Docket No. 15-015-U
(1)
LN
83
(2)
Account
128X09
84
(3)
Account Title
Decomm Trust-CF Reclass
(4)
Account Description
Accounts ending in "X06", "X07, "X08", and "X09" were created for
the sole purpose of being able to journalize certain cash flow
statement reclassifications into the general ledger. These
accounts do not contain any original operational transactions.
They are simply used to modify cash flow statement line item
presentations in Entergy's internally generated cash flow
statements.
Current and Accrued Assets
85
131000
Cash
86
131X08
Proceeds from Sale of Asset
87
131X09
Cash Paid-Acquisition
88
134000
Other Special Deposits
89
134003
Escrow Funds
90
134013
ISO Special Deposits
91
134024
Deposit-Row Transmission
92
135000
Working Funds
93
13500N
Nuc Trans- Employee Advance
94
135974
Outstanding Checks - Payroll
95
136000
Temporary Cash Investments
This account shall include the amount of current cash funds
except working funds.
Accounts ending in "X06", "X07, "X08", and "X09" were created for
the sole purpose of being able to journalize certain cash flow
statement reclassifications into the general ledger. These
accounts do not contain any original operational transactions.
They are simply used to modify cash flow statement line item
presentations in Entergy's internally generated cash flow
statements.
Accounts ending in "X06", "X07, "X08", and "X09" were created for
the sole purpose of being able to journalize certain cash flow
statement reclassifications into the general ledger. These
accounts do not contain any original operational transactions.
They are simply used to modify cash flow statement line item
presentations in Entergy's internally generated cash flow
statements.
This account shall include deposits with fiscal agents or others for
special purposes other than the payment of interest and
dividends. Such special deposits may include cash deposited with
federal, state, or municipal authorities as a guaranty for the
fulfillment of obligations; cash deposited with trustees to be held
until mortgaged property sold, destroyed, or otherwise disposed of
is replaced; cash realized from the sale of the accounting utility's
securities and deposited with trustees to be held until invested in
property of the utility, etc. Entries to this account shall specify the
purpose for which the deposit is made.
To record the cash held in escrow from capital contribution
funding.
This account reflects Northern Iowa Windpower's (NIWP) margin
deposits made to MISO (Midcontinent Independent System
Operator, Inc.) as collateral for buying and sellling power in its
market.
The EAI account was opened to record EAI's share of prefunding
sent to Entergy Services, Inc. to fund the Right of Way
Transmission & Right of Distribution Accounts. The funds will be
returned when the account is closed.
This account shall include cash advanced to officers, agents,
employees, and others as petty cash or working funds.
This account includes payroll advances for VY Security
employees, VY 64 hr transition, Palisades weekly to bi-weekly,
and NYPA transition
This account will record all cash transactions (deposits, checks
paid, other debits and credits) related to the issuance of payroll
checks for all legal entities.
This account shall include the book cost of investments, such as
demand and time loans, bankers' acceptances, United States
Treasury certificates, marketable securities, and other similar
investments, acquired for the purpose of temporarily investing
cash.
E-9 Page 7 of 99
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41 Schedule E-9
Arkansas Public Service Commission
Chart of Accounts
Minimum Filing Requirements
Partially Projected Test Year Ended
Entergy Arkansas, Inc.
March 31, 2015
Docket No. 15-015-U
(1)
LN
(2)
Account
(3)
Account Title
(4)
Account Description
96
141000
Notes Receivable
This account shall include the book cost, not includible elsewhere,
of all collectible obligations in the form of notes receivable and
similar evidences of money due on demand or within one year
from the date of issue, except, however, notes receivable from
associated companies.
This account should include customer accounts receivable
amounts due from customers for utility service and merchandise.
97
142010
Service
98
142011
Cust Accts Receiv Clearing
99
142020
Customer Care Payments In Susp
100
142021
Cust Ar Clearing (Edi)
101
142022
Cust Ar Clearing (Refunds)
102
142023
Cust Ar Clearing (Rpc)
103
142025
Cust Ar Clearing (Aps)
This account contains payments from customers on their
electricity bill. These payments are collected at walk-in agents.
These funds are collected from CheckFreePay Corp and the
Entergy Customer Care Centers. The payments post as CS1
items from CCS and the payments are cleared by Cash
Accounting at month end when cash is booked on a CSH journal.
NSF item and APS Adj files are additional items in CCS that are
paid through PEARL. NSF's and APS Adj files can only be cleared
through this payment method. Funds are not deducted on a daily
basis out of the funds that CFP sends to Bank of America.
104
142027
Cust AR Clearing (Phone Paymts
105
142999
Storm Cost Recovery
106
143000
Other Accounts Receivable
107
143007
Arm Customer
108
109
143026
143050
Arm Clearing
Unbilled Accts Receivable Mar
110
143074
MISO Receivable
111
143076
Residual Load Receivable
112
143850
MISO Transmission Receivable
113
143908
Accts Rec Seri (Balancing)
This account is used to track the balance of credit card payments
(phone payment) from customers.
This Customer Accounts Receivable account will be used for
storm damage reserve.
This account shall include amounts due the utility upon open
accounts, other than amounts due from associated companies
and from customers for utility services and merchandising, jobbing
and contract work.
Miscellaneous Accounts Receivable balance of open/unpaid
invoices.
Cash Clearing Account - Balance Should be Zero
Control account for unbilled accounts receivable that will be
cleared when item is billed in PeopleSoft Billing.
This account is a receivable from MISO for market settlement
charnges.
Receivable from external MISO market participants for LBA
residual load billing.
This account shall represent the amounts owed to Entergy's
transmission pricing zones from MISO.
This account captures the monthly O&M and capital amounts due
from SMEPA and the payments from SMEPA. SMEPA is the 10%
co-owner of the Grand Gulf Nuclear plant.
114
143959
Etec Co-Owner
The activity in this account is made up of customer payments
(posted on CS1 journals) collected through each means offered
by Entergy, RPC, EDI, CFP, and BM.
This account acts as an interim Accounts Receivable account for
CCS payments flowing to 142010.
This account collects CS1's which are automated General Ledger
postings of customer payments. The CS1's post on a daily
(business day) basis and are cleared at the end of the month by a
CSH journal posted by Cash Accounting.
Customer Information System (CCS) current outstanding
customer deposit refunds.
This account should contain CS1 postings. CS1's are daily
automated postings of customer payments. At Month End Cash
Accounting posts a CSH journal which contains all funds that are
transferred on a daily basis. RPC items are mailed in payments.
To capture cost owed EAI from east Texas Electric Coop for its
portion of the plant costs. The cost are currently captured in
account 253, resource 959. Use of this subaccount will facilitate
cleaner reporting as port of the "Smart Data" initiative.
E-9 Page 8 of 99
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41 Schedule E-9
Arkansas Public Service Commission
Chart of Accounts
Minimum Filing Requirements
Partially Projected Test Year Ended
Entergy Arkansas, Inc.
March 31, 2015
Docket No. 15-015-U
(1)
LN
(2)
Account
115
143983
Aecc Co-Owner
116
143985
Conway Co-Owner
(3)
Account Title
(4)
Account Description
This account will capture cost owed EAI from Arkansas Electric
Cooperative Corporation (AECC) for its portion of the plant costs.
The cost are currently captured in account 253, resource 983.
Use of this subaccount will facilitate cleaner reporting as port of
the "Smart Data" initiative.
This account will capture cost owed EAI from Conway for its
portion of the plant costs. The cost are currently captured in
account 253, resource 985. Use of this subaccount will facilitate
cleaner reporting as port of the "Smart Data" initiative.
117
143987
Jonesboro Co-Owner
This account will capture cost owed EAI from Jonesboro for its
portion of the plant costs. The cost are currently captured in
account 253, resource 987. Use of this subaccount will facilitate
cleaner reporting as port of the "Smart Data" initiative.
118
143992
Osceola Municipal Co-Owner
119
143995
West Memphis Utilities Co-Own
120
121
143NUC
143X09
A/R Nuclear Fuel
Receivables-CF Reclass
122
144000
Acc Prov For Uncollect Acc
123
144001
Mar Reserve-Uncollectible Acct
124
145000
Notes Rec - Associated Co.
125
146000
A/R - Affiliate
This account will capture cost owed EAI from Osceola for its
portion of the plant costs. The cost are currently captured in
account 253, resource 992. Use of this subaccount will facilitate
cleaner reporting as port of the "Smart Data" initiative.
This account will capture cost owed EAI from West Memphis
Utilities for its portion of the plant costs. The cost are currently
captured in account 253, resource 995. Use of this subaccount
will facilitate cleaner reporting as port of the "Smart Data"
initiative.
To capture miscellaneous accounts receivable nuclear fuel.
Accounts ending in "X06", "X07, "X08", and "X09" were created for
the sole purpose of being able to journalize certain cash flow
statement reclassifications into the general ledger. These
accounts do not contain any original operational transactions.
They are simply used to modify cash flow statement line item
presentations in Entergy's internally generated cash flow
statements.
This account shall be credited with amounts provided for losses
on accounts receivable which may become uncollectible, and also
with collections on accounts previously charged hereto.
Concurrent charges shall be made to account 904, Uncollectible
Accounts, for amounts applicable to utility operations, and to
corresponding accounts for other operations.
To establish a reserve for uncollectible accounts in Miscellaneous
Accounts Receivable.
Notes Receivable and Payable on inter-company loans are
booked when lender's distributed notes to affiliate companies and
when repayments is made on the Note. This is strictly related to
the note (principle).
This account shall include notes and drafts upon which associated
companies are liable, and which mature and are expected to be
paid in full not later than one year from the date of issue, together
with any interest thereon, and debit balances subject to current
settlement in open accounts with associated companies. Items
which do not bear a specified due date but which have been
carried for more than twelve months and items which are not paid
within twelve months from due date shall be transferred to
account 123, Investment in Associated Companies.
E-9 Page 9 of 99
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41 Schedule E-9
Arkansas Public Service Commission
Chart of Accounts
Minimum Filing Requirements
Partially Projected Test Year Ended
Entergy Arkansas, Inc.
March 31, 2015
Docket No. 15-015-U
(1)
LN
(2)
Account
126
146001
Money Pool - Internal Funding
127
128
146010
146018
Inter-Unit Receivable- GL/Misc
MISO Intercompany Receivable
129
146311
AR: MSS4
130
146711
AR Bulk Power/System Agreement
131
146811
A/R - Affiliate (Fuel)
132
146842
AR - AFFILIATE Misc Rec
133
146DIP
A/R-Affiliate ENOI Bankruptcy
134
146FFR
AR AFFILIATE Financial Rights
135
146X09
MYPL invest?CF reclass
136
151000
Fuel Stock
137
138
139
151100
151300
151959
Fuel Stock - Oil
Fuel Stock - Coal
Etec Co-Owner
(3)
Account Title
140
151983
Aecc Co-Owner Advances
141
151985
Conway Co-Owner Advances
142
151986
Epi Co-Owner Advances
143
151987
Jonesboro Co-Owner Advances
(4)
Account Description
The Money Pool is an internal cash management tool and
financing vehicle in which all operating companies participate,
some as borrowers and some as lenders, and as a result, bear
the benefit or cost through interest income or expense. These
accounts are maintained through a collaborative effort by
Revenue Accounting, ESI accounting, Cash Management, and
Accounts Payable.
Interest on inter-unit loans and guarantees.
Receivable between operating companies to settle cash for MISO
charges that were paid on the weekly invoices but allocated
differently in the ISB.
To book the MSS-4 calculations separately from other fuel
accounting processes
To record bulk power and system agreement intercompany
receivable from operating companies.
Contains old fuel related transactions in the intercompany
receivable account.
This intercompany receivable account represents Point-to-Point
(PTP) and Network Integration Transmission Services (NITS)
transmission service revenue. The account set up to separate
these PTP and NITS transactions from Account 146811 because
the reconciliation of this account will be performed by
Miscellaneous Receivables Department.
The balance of this account will consist of affiliate transactions
related to ENOI Bankruptcy which have yet to be funded and/or in
the process of review by PWC and Entergy’s ENOI bankruptcy
team to determine funding eligibility.
To track financial rights due to one or more Entegry op cos.
funding supplemental upgrades to transmission structures
Accounts ending in "X06", "X07, "X08", and "X09" were created for
the sole purpose of being able to journalize certain cash flow
statement reclassifications into the general ledger. These
accounts do not contain any original operational transactions.
They are simply used to modify cash flow statement line item
presentations in Entergy's internally generated cash flow
statements.
This account reflects the fuel oil inventory valued at acquisition.
This account includes the book cost of fuel oil on hand.
This account includes the book cost of fuel coal on hand.
This account will capture the advances for fuel inventory from
East Texas Electric Coop to EAI. The cost are currently captured
in account 253, resource 959. Use of this subaccount will
facilitate cleaner reporting as port of the "Smart Data" initiative.
This account will capture the advances for fuel inventory from
AECC. The cost are currently captured in account 253, resource
983. Use of this subaccount will facilitate cleaner reporting as port
of the "Smart Data" initiative.
This account will capture the advances for fuel inventory from
Conway Corp to EAI. The cost are currently captured in account
253, resource 985. Use of this subaccount will facilitate cleaner
reporting as port of the "Smart Data" initiative.
This account will capture the advances for fuel inventory from EPI
to EAI. The cost are currently captured in account 253, resource
986. Use of this subaccount will facilitate cleaner reporting as port
of the "Smart Data" initiative.
This account will capture the advances for fuel inventory from
Jonesboro. The cost are currently captured in account 253,
resource 987. Use of this subaccount will facilitate cleaner
reporting as port of the "Smart Data" initiative.
E-9 Page 10 of 99
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41 Schedule E-9
Arkansas Public Service Commission
Chart of Accounts
Minimum Filing Requirements
Partially Projected Test Year Ended
Entergy Arkansas, Inc.
March 31, 2015
Docket No. 15-015-U
(1)
LN
(2)
Account
144
151989
Emi Co-Owner Advances
145
151992
Osceola Municipal Co-Owner Adv
146
151X09
Inventory-CF Reclass
147
151995
West Memphis Co-Owner Advances
(3)
Account Title
(4)
Account Description
This account will capture the advances for fuel inventory from EMI
to EAI. The cost are currently captured in account 253, resource
989. Use of this subaccount will facilitate cleaner reporting as port
of the "Smart Data" initiative.
This account will capture the advances for fuel inventory from
Osceola Municipal POwer & Light to EAI. The cost are currently
captured in account 253, resource 992. Use of this subaccount
will facilitate cleaner reporting as port of the "Smart Data"
initiative.
Accounts ending in "X06", "X07, "X08", and "X09" were created for
the sole purpose of being able to journalize certain cash flow
statement reclassifications into the general ledger. These
accounts do not contain any original operational transactions.
They are simply used to modify cash flow statement line item
presentations in our internally generated cash flow statements.
This account will capture the advances for fuel inventory from
West Memphis Utilities to EAI. The cost are currently captured in
account 253, resource 995. Use of this subaccount will facilitate
cleaner reporting as port of the "Smart Data" initiative.
This account may include the cost of labor and of supplies used
and expenses incurred in unloading fuel from the shipping
medium and in the handling thereof prior to its use, if such
expenses are sufficiently significant in amount to warrant being
treated as a part of the cost of fuel inventory rather than being
charged direct to expense as incurred.
This account shall include the cost of materials purchased
primarily for use in the utility business for construction, operation
and maintenance purposes. For both Major and Nonmajor utilities,
it shall include also the book cost of materials recovered in
connection with construction, maintenance or the retirement of
property, such materials being credited to construction,
maintenance or accumulated depreciation provision, respectively.
148
152000
Fuel Stock Exp. Undistributed
149
154000
Plant Matls And Operating Sup
150
154100
General Inventory
151
154150
Inventory-Transformer Repair
152
154300
Inventory Suspense
153
154301
Nuclear Inv Returnd For Repair
154
154302
Transmission Reel Deposits
155
154COA
General Inventory - Co-Owner
156
154PAS
General Inventory-Passport
To capture purchase of general inventory items using the Indus
PassPort subsidiary system and to be used with Activity GINP.
157
158100
Allowance Inventory
This account shall include the cost of allowances owned by the
utility and not withheld by the Environmental Protection Agency.
Represents EPI's ownership share of M&S Inventory at
Independence and Ritchie. EPI owns a 7.18% interest in
Independence and a 100% interest in Ritchie 2.
Inventory sub account that represents the value of transformers
sent out for repair.
This is an inventory suspense account used to capture the value
progress payments made to the vendor on inventory as a part of
the purchase negotiation.
Inventory sub account that represents the value of general
inventory sent out for repair.
This account is an inventory sub-account for Accounts Payable
payments to Alcan Cable Corp. for Transmission reels of wire
purchased on a Purchase Order in Asset Suite and refunded via
check from the vendor that is recorded in Accounts Receivable.
The balance in this account represents outstanding deposits
awaiting a refund.
To capture purchase of general inventory items using the Indus
PassPort subsidiary system and to be used with Activity GINC.
E-9 Page 11 of 99
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41 Schedule E-9
Arkansas Public Service Commission
Chart of Accounts
Minimum Filing Requirements
Partially Projected Test Year Ended
Entergy Arkansas, Inc.
March 31, 2015
Docket No. 15-015-U
(1)
LN
(2)
Account
158
158150
NOX Allowance Inventory
159
158151
NOX Seasonal Allowance
160
163000
Stores Expenses Undistributed
161
165000
Prepayments
This account shall include amounts representing prepayments of
insurance, rents, taxes, interest and miscellaneous items, and
shall be kept or supported in such manner as to disclose the
amount of each class of prepayment.
162
163
165004
16500N
Pp Taxes-Regulatory Commis.
Nuc Trans- Prepayments
164
165100
Prepaid Insurance
165
165101
Pp Taxes - Franchise - Ar
To amortize Regulatory Comm taxes for EAI.
Activity in this account represents sponsorship of Nuclear Indy car
(Racing 78) which will be amortized through the year.
This is the asset account representing prepaid insurance that is
amortized monthly over the life of the insurance policy it
represents.
This account includes corporate franchise taxes for Arkansas.
166
165143
Ano#1 Shutdown Costs
167
165200
Prepaid Ins Liability-Co-Owner
168
165201
Pp Tax-Hwy Use Tax
169
165400
Prepaid Ins Directors&Officers
170
171
165403
165506
Pp Taxes Franchise-La
Prepaid Dues - INPO
172
165507
Prepaid Dues - Nuc Energy Inst
173
165508
Prepaid Fees - FEMA
174
165510
Prepaid Dues to EEI
175
165511
Prepaid Contract with STARS
176
165525
Prepaid NRC Dues
177
165603
PPD IQNavigator,Inc.
178
165611
PPD GE Intelligent Platforms
(3)
Account Title
(4)
Account Description
This account will be used to record the inventory cost of
allowances purchased in order to comply with EPA regulations for
NOX emissions. Purchases will begin in 2008 with compliance
required with the program in 2009.
Inventory account to record NOX allowances to meet
requirements of new CAIR regulations.
This account shall include the cost of supervision, labor and
expenses incurred in the operation of general storerooms,
including purchasing, storage, handling and distribution of
materials and supplies. This account is cleared by adding to the
cost of materials and supplies issued a suitable loading charge
which will distribute the expense equitably over stores issues.
This account is used to capture the costs of oil, daily lease
charges, use tax, real & property taxes during a plant outage as a
prepaid for both the AN1 and AN2 units. The costs are then
amortized over the remaining months to the next refueling outage
(approximately 54 months per unit).
This is the asset account representing prepaid insurance that is
amortized monthly over the life of the insurance policy it
represents.
Federal Highway Use Tax applies to all highway motor vehicles
having a gross weight of 55,000 pounds or more. Account activity
is the prepayment of this tax and the amortization of that prepaid
to expense.
This is the asset account representing prepaid insurance on
directors and officers. It is amortized monthly over the life of the
insurance policy it represents.
Corporate franchise taxes for Louisiana.
Account is used to track the amount of prepaid dues with Institute
of Nuclear Power Operations (INPO).
This account is used to track the amount of prepaid dues with
Nuclear Energy Institute.
This account is used to track the amount of prepaid dues with
FEMA.
To track the balance of prepaid dues to Edison Electric Institute.
This account is to track the balance of the STARS contract that
needs to be amortized.
This account is used to track the balance of the Nuclear
Regulatory Commission (NRC) dues.
This account is used to track the amount of prepaid contracts with
IQNavigator, Inc.
This account is used to track the amount of prepaid contracts with
GE Intelligent Platforms, Inc.
E-9 Page 12 of 99
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41 Schedule E-9
Arkansas Public Service Commission
Chart of Accounts
Minimum Filing Requirements
Partially Projected Test Year Ended
Entergy Arkansas, Inc.
March 31, 2015
Docket No. 15-015-U
(1)
LN
(2)
Account
179
165612
PPD HCL America
This account is used to track the amount of prepaid contracts with
HCL America. It is reconciled by comparing the General Ledger
balance to the balance of the contracts amortization schedule.
The normal balance of this account is a debit balance that
decreases each month at a steady rate until it reaches zero.
180
165RNT
Prepaid Rent Expense
181
165SAI
PrePaid Designated Servic-SAIC
182
165X09
Other Work Cap.-CF Reclass
183
171000
Interest & Dividend Rec
This account is used for prepaid rent expense that occurs
monthly, quarterly and yearly.
To record Entergy's prepayment for designated services to be
performed by SAIC.
Accounts ending in "X06", "X07, "X08", and "X09" were created for
the sole purpose of being able to journalize certain cash flow
statement reclassifications into the general ledger. These
accounts do not contain any original operational transactions.
They are simply used to modify cash flow statement line item
presentations in Entergy's internally generated cash flow
statements.
This account shall include the amount of interest on bonds,
mortgages, notes, commercial paper, loans, open accounts,
deposits, etc., the payment of which is reasonably assured, and
the amount of dividends declared or guaranteed on stocks owned.
184
172000
Misc Rents Rec (Control)
185
173000
Accrued Unbilled Revenues
186
173001
Unbilled Revenue-Wholesale
187
174000
Misc Current & Accrued Asset
188
174101
Unbilled Storm Jobbing Orders
189
174104
Refueling Outage
(3)
Account Title
190
174200
Unbilled External Jobbng Ordrs
191
174899
Misc Curnt & Accrd Assets
192
175200
Derivative Instr - MISO FTRs
193
194
(4)
Account Description
This account shall include rents receivable or accrued on property
rented or leased by the utility to others.
At the option of the utility, the estimated amount accrued for
service rendered, but not billed at the end of any accounting
period, may be included herein. In case accruals are made for
unbilled revenues, they shall be made likewise for unbilled
expenses, such as for the purchase of energy.
This account records and tracks unbilled revenue for wholesale
customers.
This account shall include the book cost of all other current and
accrued assets, appropriately designated and supported so as to
show the nature of each asset included herein.
This account captures activities that concern External Job Orders
and Storm Job Orders.
This account collects the costs associated with the refueling
outage of the plant. Once the outage is complete, the costs are
finalized and then moved to account 174109 to be amortized.
This account represents activity of External Job Orders. The
charges that hit these projects are fully reimbursable to the
Entergy by the customer at the completion of the project.
This account represents a manual re-allocation of inter-company
interest income and interest expense elimination among certain
elimination buisness units within the non-regulated nuclear group.
This account shall be used to record Financial Transmission
Rights (FTRs) granted from MISO.
Deferred Debits
181000
Unamortized Debt Expense
This account shall include expenses related to the issuance or
assumption of debt securities. Amounts recorded in this account
shall be amortized over the life of each respective issue under a
plan which will distribute the amount equitably over the life of the
security. The amortization shall be on a monthly basis, and the
amounts thereof shall be charged to account 428, Amortization of
Debt Discount and Expense. Any unamortized amounts
outstanding at the time that the related debt is prematurely
reacquired shall be accounted for as indicated in USOA General
Instruction 17.
E-9 Page 13 of 99
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41 Schedule E-9
Arkansas Public Service Commission
Chart of Accounts
Minimum Filing Requirements
Partially Projected Test Year Ended
Entergy Arkansas, Inc.
March 31, 2015
Docket No. 15-015-U
(1)
LN
(2)
Account
(3)
Account Title
195
181CPD
Unamort. Debt Expense (CPD)
196
181CPI
Unamortized bond insurance
197
182300
Oth Reg Assts-Decom & Decontam
198
182301
Reg Assets - Fas109 - Federal
199
182302
Regulatory Assets - Fas 106
200
182303
Gg1 Costs-Under Recvry-Noncurr
201
182312
Ises Synchronization Adjustmnt
202
182335
Electric Def Fuel Under Reco
203
18234A
Fed Litigation Consulting Fees
204
182357
Reg Asset - 30Yr Retail
205
18235A
Reg Asset - MISO FTR M-T-M
206
182362
Reg Asset - Asset Retire Oblig
207
182372
Reg Asset-ARO-Fossil Steam Pro
208
182373
Reg Asset - ARO - Hydro Produc
209
182377
Reg Asset-ARO-Other Production
210
182381
Regulatory Asset SFAS 158
211
182383
SFAS158 Reg Asset Offset Pt D
212
18238B
Reg Asset-EAI 2009 Ice Storm
213
182390
Under-collect of Sys Agree Cts
214
182391
Reg Asset-sys agrmnt bandwidth
215
182394
CA Rider Over/Under Recovery
(4)
Account Description
This account represents expenses related to long-term financing
that will be expensed over the life of their respective bonds. This
account was set up to faciliate the automation of the cash flow
statement.
To record bond insurance payments as unamortized debt
expense for future monthly amortization over the life of the
insurance term.
This account is the regulatory asset account that captures the
estimated costs payable to the DOE for decommissioning and
decontamination (special assessment).
This account represents the Regulatory Asset related to FAS109.
This account represents the regulatory difference between the
FAS 106 accrual and pay as you go costs. In December 1997 the
APSC ruled that EAI could begin to amortize the accrued balance
as of 12/31/97 ($35,902,504) over 15 years beginning in Jan 1998
($199,455 PER MONTH) The entire balance will be amortized to
zero by 2013.
This account is used to record the deferral of the over and under
recoveries related to the EAI Grand Gulf Rider.
This account consists of deferred O&M startup costs which were
reclassed from account 303. Monthly amortization of $34,036.00
has occurred and will continue to occur for a period of 360 months
beginning September 1983 and ending August 2013.
This account should include all under-recoveries of electric
expense.
This account shall be used to account for federal litigation
consulting fees.
Balance represents EAI's 2000 ice storm costs in excess of TCA
per the 06/2002 Stipulation & Settlement Agreement. The excess
has been set up as a regulatory asset to be amortized over thirty
years.
This account records the mark-to-market impacts associated with
MISO FTR valutions.
This account should record the regulatory assets held by EAI Unit
1 & 2 as required by SFAS 143.
To record the regulatory asset resulting from the difference in
financial reporting of asbestos asset retirement obligations at
fossil generating units and the rate recovery of those costs.
To record the regulatory asset resulting from the difference in
financial reporting of asbestos asset retirement obligations at
hydro generating units and the rate recovery of those costs.
To record the regulatory asset resulting from the difference in
financial reporting of asbestos asset retirement obligations at
other generating units and the rate recovery of those costs.
To track changes to Regulatory Assets as a result of a new FASB
Standard No. 158 Employers’ Accounting for Defined Benefit
Pension and Other Postretirement Benefit Plans.
This account records changes to the tax impact of the Medicare
Part D Subsidy permanent difference.
This account captures deferred Capital and O&M costs to be
funded by securitization proceeds for EAI. Regulatory asset will be
sold to Bondco and decreased by cust collections.
This account records the under collection from customers of
system agreement costs
This account records the amount of FERC ordered System
Agreement bandwith remedy payments which will be refunded to
customers within the next 12 months.
This account records deferral of LTSA payment made and
expensed October 2008 and to be collected through EAI CA rider
beginning August 2009.
E-9 Page 14 of 99
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41 Schedule E-9
Arkansas Public Service Commission
Chart of Accounts
Minimum Filing Requirements
Partially Projected Test Year Ended
Entergy Arkansas, Inc.
March 31, 2015
Docket No. 15-015-U
(1)
LN
(2)
Account
216
182396
Energy Eff Prog Over/Under Rec
217
18239B
EAI RPCE Reg Asset-NONCUR
218
219
18239C
1823A3
Under Recovery - Rider CCR
Reg Asset - 2013 EAI Rate Case
220
1823A9
REG ASSET 2009 EAI RATE CASE
221
1823AN
ANOR Regulatory Asset
222
1823EE
EAI Energy Efficiency Program
223
1823FR
Reg asset-property ins. prov.
224
1823HC
HCM Deferral
This account will be used to defer Human Capital Management
related costs in accordance with regulatory orders.
225
1823IL
Def Interrupt Load Refund Col
226
1823LC
Reg Asset - Lake Caherine 4
This account is used for the deferral for amount of interruptible
load refund payments to be collected from customers. Account is
needed to track amount to be deferred for future collection from
cusomters as a result of a FERC settlement resulting in a refund
in the interruptible load case.
To defer Lake Catherine 4 reliability sustainability project costs per
APSC Docket 12-028-U. Use with activity code RDRA.
227
1823LG
Reg Asset -Little Gypsy Unit 3
228
229
1823M4
1823MD
Under Recovery - MISO Rider
MISO Cost Deferral
230
1823MK
MOARK Regulatory Asset
231
1823SC
Reg Asset - RTO Study Costs
232
182X01
Def Fuel Asset Reclass
(3)
Account Title
(4)
Account Description
This account will be used to record the over/underrecovery of
costs associated with the Energy Efficiency program.
This account records costs pertaining to the APSC rate filing
where EAI is getting recovery of 2011 RCPE (Rough Production
Cost Equalization) payments over 21 months April 2012 to Dec
2013.
Under recovery of costs associated with EAI Rider CCR.
This account will be used to establish a regulatory asset for costs
the APSC allowed for deferral and amortization related to the
2013 Entergy Arkansas rate case.
This account establishes a regulatory asset for costs the APSC
allowed for deferral and amortization related to the 2009 Entergy
Arkansas rate case.
Regulatory asset for under recovery balance of Arkansas Nuclear
One, Unit 1 Interim Capacity Cost Recovery Rider (Rider ANOR).
The regulatory asset should be amortized as the balance is
collected through rates effective May 1, 2014 through December
31, 2014. Order No. 16, Docket 13-028-U
This account accumulates applicable costs associated w/the
Energy Efficiency Program ordered by the APSC. Costs will be
billed to customers under an exact recovery rider .
This account is used to move debit balances in accumulated
provision for property insurance subaccounts 228.1 to a regulatory
asset 182.3 subaccount to comply with FERC reporting.
This account records accumulated charges related to the
cancelled Little Gypsy Unit 3 Repowering Project to be recovered
from customers in a fair and appropriate manner.
Under recovery of costs associated with MISO Rider.
This account will be used to defer MISO transition costs. Reg
asset associated with the recording of MISO Cost Deferral.
Regulatory asset for the deferral of MOARK costs recorded in
FERC accounts 566 and 570. The reg asset should be amortized
back to 566 and 570 consistent with recovery. Expenses are
related to the MOARK agreement per the Amended and Restated
Interchange Agreement between Entergy Arkansas, Inc.
Associated Electric Cooperative, Inc. and Union Electric Company
dated July 29, 2011.
This account is used to accumulate the costs of the SPP RTO
study pursuant to APSC docket 08-136-U.
Accounts ending in "X01", "X02", "X03", and "X04" were created
for the sole purpose of being able to journalize certain balance
sheet statement reclassifications into the general ledger. These
accounts do not contain any original operational transactions.
They are simply used to modify the balance sheet statement line
item presentations in Entergy's internally generated balance sheet
statements.
E-9 Page 15 of 99
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41 Schedule E-9
Arkansas Public Service Commission
Chart of Accounts
Minimum Filing Requirements
Partially Projected Test Year Ended
Entergy Arkansas, Inc.
March 31, 2015
Docket No. 15-015-U
(1)
LN
(2)
Account
233
182X03
Def Fuel-Reg Investment Dr
234
182X04
Def Fuel-Reg Investment Cr
235
182X05
Def. Fuel Asset - LT Reclass
236
182X09
Other Reg. Assets-CF Reclass
237
183000
Preliminary Survey & Invtg Ch
238
184000
Clearing Accounts
239
184001
Operations Vehicle
240
18400G
Non-Productive Time Gen
241
1840FS
Transportation Clearing-Fossil
242
1840NC
Transportation Clearing_Nuc
243
184100
Storm Card Clearing
244
184EST
Safety Training Loader
(3)
Account Title
(4)
Account Description
Accounts ending in "X01", "X02", "X03", and "X04" were created
for the sole purpose of being able to journalize certain balance
sheet statement reclassifications into the general ledger. These
accounts do not contain any original operational transactions.
They are simply used to modify the balance sheet statement line
item presentations in Entergy's internally generated balance sheet
statements.
Accounts ending in "X01", "X02", "X03", and "X04" were created
for the sole purpose of being able to journalize certain balance
sheet statement reclassifications into the general ledger. These
accounts do not contain any original operational transactions.
They are simply used to modify the balance sheet statement line
item presentations in Entergy's internally generated balance sheet
statements.
Account will be used to reclassify amounts in the deferred fuel
current asset line to the deferred fuel non-current asset line as
required for balance sheet presentation
Accounts ending in "X06", "X07, "X08", and "X09" were created for
the sole purpose of being able to journalize certain cash flow
statement reclassifications into the general ledger. These
accounts do not contain any original operational transactions.
They are simply used to modify cash flow statement line item
presentations in Entergy's internally generated cash flow
statements.
This account shall be charged with all expenditures for preliminary
surveys, plans, investigations, etc., made for the purpose of
determining the feasibility of utility projects under contemplation.
This account shall include undistributed balances in clearing
accounts at the date of the balance sheet.
AP, Transportation Clearing Allocation, Transportation Shop
Payroll and ARM for vehicle sales. Rates per vehicle class per
Business Unit are set in the VEA application and clear charges
through the allocation from 184001 to O&M/Capital accounts. The
rates are multiplied by the hours of usage per vehicle recorded in
VEA on a monthly basis.
This account should include Entergy Arkansas, Inc.'s nonproductive time (e.g., vacation, holidays, etc.) (PR1). The account
should also include the offset to the unused vacation accrual,
which accrued in account 232VAC. The account is cleared over
the course of the year through the non-productive loader process
(PR5). A standard rate is applied against regular and overtime
(i.e., productive time). The loaded record of the allocation
charges back to productive time by detail Org.
A clearing account for the fossil transportation allocation.The
majority of costs should come from any ESI overhead depts that
provide services to Fossil's transportation. Acct will be cleared
with an EPM allocation
This account will be used as a clearing account for the nuclear
transportaton allocation. The majority of the costs should come
from any ESI overhead departments that provide services for
Nuclear's transportation.
This account is used to track the storm card purchases between
Business Units.
This account is used to as a clearing account for a new safety
training allocation.
E-9 Page 16 of 99
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41 Schedule E-9
Arkansas Public Service Commission
Chart of Accounts
Minimum Filing Requirements
Partially Projected Test Year Ended
Entergy Arkansas, Inc.
March 31, 2015
Docket No. 15-015-U
(1)
LN
(2)
Account
245
186000
Miscellaneous Deferred Debits
For Major utilities, this account shall include all debits not
elsewhere provided for, such as miscellaneous work in progress,
and unusual or extraordinary expenses, not included in other
accounts, which are in process of amortization and items the
proper final disposition of which is uncertain.
246
186013
Employee Purchased Equipment
247
186080
Active Development Costs
248
186100
Miscellaneous Other / Suspense
To record employee purchased tools that are eligible for payroll
deduction.
This account records projects that are in the active development
stage. The costs are expensed or capitalized according to project
code or stage fractivity.
This is used by the Affiliate Systems group to account for items
that were erroneously billed to unbillable companies. They put
those amounts in this deferred account until they research and
determine which company it should have been charged to.
249
186263
Section 263A
250
186700
Pooled Equipment - PEICo
251
186800
Deferred Debit-System Benefit
252
186801
Def. Dr. Syst. Ben-post 2002
253
186ACL
Non-Expense Accrued Labor
254
186AM1
EAI Agric Irrig AMI Load Cntrl
255
186APC
AP Account Conversion Suspense
256
186EMP
Employee Direct Dep-Clearing
257
186ESR
Extraordinary Storm Restor Cst
258
186MTM
Mark to Market
259
260
186SAI
186SFC
Saic Ap Clearing
Misc Def Debit-Sectz Fin Cost
261
186U29
Costs Associated With Nfip
262
186UPA
UPSA - Mark to Market
(3)
Account Title
(4)
Account Description
This account is required to capture expenses associated with IRS
Section 263A research so costs may be considered for
amortization / recovery over life of tax benefits.
To capture Entergy's contractual interest in PEICo managed
Pooled Equipment. The nuclear industry's response to the
Fukushima Incident and following NRC Orders involves creating
a FLEXable coping strategy for dealing with loss of offsite power
and station blackout. As part of this FLEX strategy, Entergy will
modify each reactor to accept FLEX equipment that will be
managed by PEICo and stored in Regional Response Centers in
Arizona and Tennessee
This account reflects the company's stock option costs (i.e. the
gain paid to employees). Cash was paid to ETR Parent. Costs
being amortized over 3 year periods.
This account reflects the company's stock option costs (i.e. the
gain paid to employees) for post 2002 grants whose exercise gain
was in excess of valuation expense. Cash was paid to ETR
Parent. Costs being amortized over 3 year periods.
This account records the non-expense portion of the monthly
accrual of employee salaries.
This account records Irrigation Load Control Services recovered in
the Energy Efficiency Revenue Rider.
This account captures items that were processed prior to 8.4
conversion that were cancelled and the code block is no longer
valid.
A clearing account for reissues relating to Employee Direct
Deposits that have been returned to Bank One due to some type
of error on employee's banking account information.
To record Extraordianry Storm Restoration costs in support of
APSC Docket #08-149-U.
To capture costs associated with Mark to Market Vidalia contract
activities.
This account is a clearing account for SAIC invoices.
The amortization related to costs incurred from Entergy Ark 09 Ice
Storm Securitization.
This account captures any legal or administrative fees that apply
to ANO. These costs are put under the fuel lease in the month
following quarter end and then moved to the nuclear fuel inventory
account.
To capture costs associated with mark to market Unit Power
Sales Agreement activities.
E-9 Page 17 of 99
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41 Schedule E-9
Arkansas Public Service Commission
Chart of Accounts
Minimum Filing Requirements
Partially Projected Test Year Ended
Entergy Arkansas, Inc.
March 31, 2015
Docket No. 15-015-U
(1)
LN
(2)
Account
263
186X09
Other OCF Reclass
264
189000
Unamortized Loss On Reacq Deb
265
189CPD
Unamort loss-reacq debt (CPD)
266
190111
Intrst/Tax-Tax Deficienci-Fed
267
190112
Intrst/Tax-Tax Deficienci-St
268
190121
ANO Shutdown Costs - Fed
269
190122
ANO Shutdown Costs - State
(3)
Account Title
(4)
Account Description
Accounts ending in "X06", "X07, "X08", and "X09" were created for
the sole purpose of being able to journalize certain cash flow
statement reclassifications into the general ledger. These
accounts do not contain any original operational transactions.
They are simply used to modify cash flow statement line item
presentations in Entergy's internally generated cash flow
statements.
This account shall include the losses on long-term debt reacquired
or redeemed. The amounts in this account shall be amortized in
accordance with USOA General Instruction 17.
This account represents unamortized loss on reacquired longterm debt. This account was set up to facilitate the automation of
the cash flow statement.
This account shall be debited and account 411.1, Provision for
Deferred Income Taxes - Credit, Utility Operating Income, or
Account 411.2, Provision for Deferred Income Taxes - Credit,
Other Income and Deductions, as appropriate, shall be credited
with an amount equal to that by which income taxes payable for
the year are higher because of the inclusion of certain items in
income for tax purposes, which items for general accounting
purposes will not be fully reflected in the utility's determination of
annual net income until subsequent years. This subaccount of
190 accounts for the federal taxes representing the elimination of
the book accrual for interest on tax deficiencies which are
deductible for tax when paid.
This account shall be debited and account 411.1, Provision for
Deferred Income Taxes - Credit, Utility Operating Income, or
Account 411.2, Provision for Deferred Income Taxes - Credit,
Other Income and Deductions, as appropriate, shall be credited
with an amount equal to that by which income taxes payable for
the year are higher because of the inclusion of certain items in
income for tax purposes, which items for general accounting
purposes will not be fully reflected in the utility's determination of
annual net income until subsequent years. This subaccount of
190 accounts for the state taxes representing the elimination of
the book accrual for interest on tax deficiencies which are
deductible for tax when paid.
This account shall be debited and account 411.1, Provision for
Deferred Income Taxes - Credit, Utility Operating Income, or
Account 411.2, Provision for Deferred Income Taxes - Credit,
Other Income and Deductions, as appropriate, shall be credited
with an amount equal to that by which income taxes payable for
the year are higher because of the inclusion of certain items in
income for tax purposes, which items for general accounting
purposes will not be fully reflected in the utility's determination of
annual net income until subsequent years. This subaccount of
190 accounts for the federal taxes related to ANO shutdown costs
recorded in FERC account 165143, ANO#1 Shutdown Costs.
This account shall be debited and account 411.1, Provision for
Deferred Income Taxes - Credit, Utility Operating Income, or
Account 411.2, Provision for Deferred Income Taxes - Credit,
Other Income and Deductions, as appropriate, shall be credited
with an amount equal to that by which income taxes payable for
the year are higher because of the inclusion of certain items in
income for tax purposes, which items for general accounting
purposes will not be fully reflected in the utility's determination of
annual net income until subsequent years. This subaccount of
190 accounts for the state taxes related to ANO shutdown costs
recorded in FERC account 165143 ANO#1 Shutdown Costs.
E-9 Page 18 of 99
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41 Schedule E-9
Arkansas Public Service Commission
Chart of Accounts
Minimum Filing Requirements
Partially Projected Test Year Ended
Entergy Arkansas, Inc.
March 31, 2015
Docket No. 15-015-U
(1)
LN
(2)
Account
270
190131
Ggi-Arrc-Over/Under Rcv-Fed
271
190132
Ggi-Arrc-Over/Under Rcv-St
272
190151
Taxable Unbilled Revenue-Fed
273
190152
Taxable Unbilled Revenue-St
(3)
Account Title
(4)
Account Description
This account shall be debited and account 411.1, Provision for
Deferred Income Taxes - Credit, Utility Operating Income, or
Account 411.2, Provision for Deferred Income Taxes - Credit,
Other Income and Deductions, as appropriate, shall be credited
with an amount equal to that by which income taxes payable for
the year are higher because of the inclusion of certain items in
income for tax purposes, which items for general accounting
purposes will not be fully reflected in the utility's determination of
annual net income until subsequent years. This subaccount of
190 accounts for the federal taxes related to the recovery of
Grand Gulf costs.
This account shall be debited and account 411.1, Provision for
Deferred Income Taxes - Credit, Utility Operating Income, or
Account 411.2, Provision for Deferred Income Taxes - Credit,
Other Income and Deductions, as appropriate, shall be credited
with an amount equal to that by which income taxes payable for
the year are higher because of the inclusion of certain items in
income for tax purposes, which items for general accounting
purposes will not be fully reflected in the utility's determination of
annual net income until subsequent years. This subaccount of
190 accounts for the state taxes related to the recovery of Grand
Gulf costs.
This account shall be debited and account 411.1, Provision for
Deferred Income Taxes - Credit, Utility Operating Income, or
Account 411.2, Provision for Deferred Income Taxes - Credit,
Other Income and Deductions, as appropriate, shall be credited
with an amount equal to that by which income taxes payable for
the year are higher because of the inclusion of certain items in
income for tax purposes, which items for general accounting
purposes will not be fully reflected in the utility's determination of
annual net income until subsequent years. This subaccount of
190 accounts for the federal taxes related to taxable unbilled
revenue. For tax purposes, included in taxable income, is
revenue from electricity used in the taxable period but not
included in book income until a subsequent period. This timing
difference includes both the unbilled revenue for the current year
and the reversal of current year's book income previously
recognized for tax purposes.
This account shall be debited and account 411.1, Provision for
Deferred Income Taxes - Credit, Utility Operating Income, or
Account 411.2, Provision for Deferred Income Taxes - Credit,
Other Income and Deductions, as appropriate, shall be credited
with an amount equal to that by which income taxes payable for
the year are higher because of the inclusion of certain items in
income for tax purposes, which items for general accounting
purposes will not be fully reflected in the utility's determination of
annual net income until subsequent years. This subaccount of
190 accounts for the state taxes related to taxable unbilled
revenue. For tax purposes, included in taxable income, is
revenue from electricity used in the taxable period but not
included in book income until a subsequent period. This timing
difference includes both the unbilled revenue for the current year
and the reversal of current year's book income previously
recognized for tax purposes
E-9 Page 19 of 99
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41 Schedule E-9
Arkansas Public Service Commission
Chart of Accounts
Minimum Filing Requirements
Partially Projected Test Year Ended
Entergy Arkansas, Inc.
March 31, 2015
Docket No. 15-015-U
(1)
LN
(2)
Account
274
190161
Property Ins Reserve-Fed
275
190162
Property Ins Reserve-State
276
190163
Capitalized Repairs - Fed
277
190164
Capitalized Repairs - State
This account shall be debited and account 411.1, Provision for
Deferred Income Taxes - Credit, Utility Operating Income, or
Account 411.2, Provision for Deferred Income Taxes - Credit,
Other Income and Deductions, as appropriate, shall be credited
with an amount equal to that by which income taxes payable for
the year are higher because of the inclusion of certain items in
income for tax purposes, which items for general accounting
purposes will not be fully reflected in the utility's determination of
annual net income until subsequent years. This subaccount of
190 accounts for the federal taxes related to storm O&M costs
capitalized and depreciated for tax.
278
190165
Syst Agrmt Equal Reg Liab-Fed
This account shall be debited and account 411.1, Provision for
Deferred Income Taxes - Credit, Utility Operating Income, or
Account 411.2, Provision for Deferred Income Taxes - Credit,
Other Income and Deductions, as appropriate, shall be credited
with an amount equal to that by which income taxes payable for
the year are higher because of the inclusion of certain items in
income for tax purposes, which items for general accounting
purposes will not be fully reflected in the utility's determination of
annual net income until subsequent years. This subaccount of
190 accounts for the federal taxes representing the inclusion in
taxable income of system agreement rough production cost
equalization payments.
(3)
Account Title
(4)
Account Description
This account shall be debited and account 411.1, Provision for
Deferred Income Taxes - Credit, Utility Operating Income, or
Account 411.2, Provision for Deferred Income Taxes - Credit,
Other Income and Deductions, as appropriate, shall be credited
with an amount equal to that by which income taxes payable for
the year are higher because of the inclusion of certain items in
income for tax purposes, which items for general accounting
purposes will not be fully reflected in the utility's determination of
annual net income until subsequent years. This subaccount of
190 accounts for the federal taxes representing the elimination of
the book accruals consisting of estimates to recover current and
future losses and deducting the costs for tax when actually
incurred.
This account shall be debited and account 411.1, Provision for
Deferred Income Taxes - Credit, Utility Operating Income, or
Account 411.2, Provision for Deferred Income Taxes - Credit,
Other Income and Deductions, as appropriate, shall be credited
with an amount equal to that by which income taxes payable for
the year are higher because of the inclusion of certain items in
income for tax purposes, which items for general accounting
purposes will not be fully reflected in the utility's determination of
annual net income until subsequent years. This subaccount of
190 accounts for the state taxes representing the elimination of
the book accruals consisting of estimates to recover current and
future losses and deducting the costs for tax when actually
incurred.
This account shall be debited and account 411.1, Provision for
Deferred Income Taxes - Credit, Utility Operating Income, or
Account 411.2, Provision for Deferred Income Taxes - Credit,
Other Income and Deductions, as appropriate, shall be credited
with an amount equal to that by which income taxes payable for
the year are higher because of the inclusion of certain items in
income for tax purposes, which items for general accounting
purposes will not be fully reflected in the utility's determination of
annual net income until subsequent years. This subaccount of
190 accounts for the federal taxes related to storm O&M costs
capitalized and depreciated for tax.
E-9 Page 20 of 99
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41 Schedule E-9
Arkansas Public Service Commission
Chart of Accounts
Minimum Filing Requirements
Partially Projected Test Year Ended
Entergy Arkansas, Inc.
March 31, 2015
Docket No. 15-015-U
(1)
LN
(2)
Account
279
190166
Sys Agrmt Equal Reg Liab-State
280
190171
Inj & Damages Reserve-Fed
281
190172
Inj & Damages Reserve-State
This account shall be debited and account 411.1, Provision for
Deferred Income Taxes - Credit, Utility Operating Income, or
Account 411.2, Provision for Deferred Income Taxes - Credit,
Other Income and Deductions, as appropriate, shall be credited
with an amount equal to that by which income taxes payable for
the year are higher because of the inclusion of certain items in
income for tax purposes, which items for general accounting
purposes will not be fully reflected in the utility's determination of
annual net income until subsequent years. This subaccount of
190 accounts for the state taxes related to the injuries and
damages reserve. This represents the elimination of the book
accruals consisting of estimates to recover current and future
losses and deducting the costs for tax when actually incurred.
282
190191
Customer Deposits-Fed
This account shall be debited and account 411.1, Provision for
Deferred Income Taxes - Credit, Utility Operating Income, or
Account 411.2, Provision for Deferred Income Taxes - Credit,
Other Income and Deductions, as appropriate, shall be credited
with an amount equal to that by which income taxes payable for
the year are higher because of the inclusion of certain items in
income for tax purposes, which items for general accounting
purposes will not be fully reflected in the utility's determination of
annual net income until subsequent years. This subaccount of
190 accounts for the federal taxes related to customer deposits.
283
190192
Customer Depsoits-State
This account shall be debited and account 411.1, Provision for
Deferred Income Taxes - Credit, Utility Operating Income, or
Account 411.2, Provision for Deferred Income Taxes - Credit,
Other Income and Deductions, as appropriate, shall be credited
with an amount equal to that by which income taxes payable for
the year are higher because of the inclusion of certain items in
income for tax purposes, which items for general accounting
purposes will not be fully reflected in the utility's determination of
annual net income until subsequent years. This subaccount of
190 accounts for the state taxes related to customer deposits.
(3)
Account Title
(4)
Account Description
This account shall be debited and account 411.1, Provision for
Deferred Income Taxes - Credit, Utility Operating Income, or
Account 411.2, Provision for Deferred Income Taxes - Credit,
Other Income and Deductions, as appropriate, shall be credited
with an amount equal to that by which income taxes payable for
the year are higher because of the inclusion of certain items in
income for tax purposes, which items for general accounting
purposes will not be fully reflected in the utility's determination of
annual net income until subsequent years. This subaccount of
190 accounts for the state taxes representing the inclusion in
taxable income of system agreement rough production cost
equalization payments.
This account shall be debited and account 411.1, Provision for
Deferred Income Taxes - Credit, Utility Operating Income, or
Account 411.2, Provision for Deferred Income Taxes - Credit,
Other Income and Deductions, as appropriate, shall be credited
with an amount equal to that by which income taxes payable for
the year are higher because of the inclusion of certain items in
income for tax purposes, which items for general accounting
purposes will not be fully reflected in the utility's determination of
annual net income until subsequent years. This subaccount of
190 accounts for the federal taxes related to the injuries and
damages reserve. This represents the elimination of the book
accruals consisting of estimates to recover current and future
losses and deducting the costs for tax when actually incurred.
E-9 Page 21 of 99
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41 Schedule E-9
Arkansas Public Service Commission
Chart of Accounts
Minimum Filing Requirements
Partially Projected Test Year Ended
Entergy Arkansas, Inc.
March 31, 2015
Docket No. 15-015-U
(1)
LN
(2)
Account
284
190211
Unfunded Pension Exp-Fed
This account shall be debited and account 411.1, Provision for
Deferred Income Taxes - Credit, Utility Operating Income, or
Account 411.2, Provision for Deferred Income Taxes - Credit,
Other Income and Deductions, as appropriate, shall be credited
with an amount equal to that by which income taxes payable for
the year are higher because of the inclusion of certain items in
income for tax purposes, which items for general accounting
purposes will not be fully reflected in the utility's determination of
annual net income until subsequent years. This subaccount of
190 accounts for the federal taxes related to unfunded pension
expense. This represents the elimination of the book accruals for
the pension plan which are deductible for tax when actually
funded or paid to the retirement trust.
285
190212
Unfunded Pension Exp-State
This account shall be debited and account 411.1, Provision for
Deferred Income Taxes - Credit, Utility Operating Income, or
Account 411.2, Provision for Deferred Income Taxes - Credit,
Other Income and Deductions, as appropriate, shall be credited
with an amount equal to that by which income taxes payable for
the year are higher because of the inclusion of certain items in
income for tax purposes, which items for general accounting
purposes will not be fully reflected in the utility's determination of
annual net income until subsequent years. This subaccount of
190 accounts for the state taxes related to unfunded pension
expense. This represents the elimination of the book accruals for
the pension plan which are deductible for tax when actually
funded or paid to the retirement trust.
286
190213
SFAS 158 Def Tax Asset - Fed
This account shall be debited and account 411.1, Provision for
Deferred Income Taxes - Credit, Utility Operating Income, or
Account 411.2, Provision for Deferred Income Taxes - Credit,
Other Income and Deductions, as appropriate, shall be credited
with an amount equal to that by which income taxes payable for
the year are higher because of the inclusion of certain items in
income for tax purposes, which items for general accounting
purposes will not be fully reflected in the utility's determination of
annual net income until subsequent years. This subaccount of
190 accounts for the federal taxes related to the Statement of
Financial Accounting Standards 158 deferred tax asset for the
deferred tax on post retirement benefit plan obligations.
287
190214
SFAS 158 Def Tax Asset - State
This account shall be debited and account 411.1, Provision for
Deferred Income Taxes - Credit, Utility Operating Income, or
Account 411.2, Provision for Deferred Income Taxes - Credit,
Other Income and Deductions, as appropriate, shall be credited
with an amount equal to that by which income taxes payable for
the year are higher because of the inclusion of certain items in
income for tax purposes, which items for general accounting
purposes will not be fully reflected in the utility's determination of
annual net income until subsequent years. This subaccount of
190 accounts for the state taxes related to the Statement of
Financial Accounting Standards 158 deferred tax asset for the
deferred tax on post retirement benefit plan obligations.
(3)
Account Title
(4)
Account Description
E-9 Page 22 of 99
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41 Schedule E-9
Arkansas Public Service Commission
Chart of Accounts
Minimum Filing Requirements
Partially Projected Test Year Ended
Entergy Arkansas, Inc.
March 31, 2015
Docket No. 15-015-U
(1)
LN
(2)
Account
288
190215
Supplemental Pension Plan-Fed
289
190216
Supplemental Pension Plan-St
290
190221
Fas 106 Other Retire Ben-Fed
291
190222
Fas 106 Other Retire Ben-State
(3)
Account Title
(4)
Account Description
This account shall be debited and account 411.1, Provision for
Deferred Income Taxes - Credit, Utility Operating Income, or
Account 411.2, Provision for Deferred Income Taxes - Credit,
Other Income and Deductions, as appropriate, shall be credited
with an amount equal to that by which income taxes payable for
the year are higher because of the inclusion of certain items in
income for tax purposes, which items for general accounting
purposes will not be fully reflected in the utility's determination of
annual net income until subsequent years. This subaccount of
190 accounts for the federal taxes related to the Supplemental
Pension Plan.
This account shall be debited and account 411.1, Provision for
Deferred Income Taxes - Credit, Utility Operating Income, or
Account 411.2, Provision for Deferred Income Taxes - Credit,
Other Income and Deductions, as appropriate, shall be credited
with an amount equal to that by which income taxes payable for
the year are higher because of the inclusion of certain items in
income for tax purposes, which items for general accounting
purposes will not be fully reflected in the utility's determination of
annual net income until subsequent years. This subaccount of
190 accounts for the state taxes related to the Supplemental
Pension Plan.
This account shall be debited and account 411.1, Provision for
Deferred Income Taxes - Credit, Utility Operating Income, or
Account 411.2, Provision for Deferred Income Taxes - Credit,
Other Income and Deductions, as appropriate, shall be credited
with an amount equal to that by which income taxes payable for
the year are higher because of the inclusion of certain items in
income for tax purposes, which items for general accounting
purposes will not be fully reflected in the utility's determination of
annual net income until subsequent years. This subaccount of
190 accounts for the federal taxes related to the Statement of
Financial Accounting Standard 106 other postretirement benefits.
This represents the elimination of the book accrual for these costs
which are deductible for tax when actually incurred.
This account shall be debited and account 411.1, Provision for
Deferred Income Taxes - Credit, Utility Operating Income, or
Account 411.2, Provision for Deferred Income Taxes - Credit,
Other Income and Deductions, as appropriate, shall be credited
with an amount equal to that by which income taxes payable for
the year are higher because of the inclusion of certain items in
income for tax purposes, which items for general accounting
purposes will not be fully reflected in the utility's determination of
annual net income until subsequent years. This subaccount of
190 accounts for the state taxes related to the Statement of
Financial Accounting Standard 106 other postretirement benefits.
This represents the elimination of the book accrual for other post
employment benefits which are deductible for tax when paid.
E-9 Page 23 of 99
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41 Schedule E-9
Arkansas Public Service Commission
Chart of Accounts
Minimum Filing Requirements
Partially Projected Test Year Ended
Entergy Arkansas, Inc.
March 31, 2015
Docket No. 15-015-U
(1)
LN
(2)
Account
292
190241
Deferred Fuel/Gas-Fed
293
190242
Deferred Fuel/Gas-St
294
190251
Removal Cost - Fed
This account shall be debited and account 411.1, Provision for
Deferred Income Taxes - Credit, Utility Operating Income, or
Account 411.2, Provision for Deferred Income Taxes - Credit,
Other Income and Deductions, as appropriate, shall be credited
with an amount equal to that by which income taxes payable for
the year are higher because of the inclusion of certain items in
income for tax purposes, which items for general accounting
purposes will not be fully reflected in the utility's determination of
annual net income until subsequent years. This subaccount of
190 accounts for the federal taxes related to removal costs. For
tax purposes, removal costs are deducted when incurred.
295
190252
Removal Cost - State
This account shall be debited and account 411.1, Provision for
Deferred Income Taxes - Credit, Utility Operating Income, or
Account 411.2, Provision for Deferred Income Taxes - Credit,
Other Income and Deductions, as appropriate, shall be credited
with an amount equal to that by which income taxes payable for
the year are higher because of the inclusion of certain items in
income for tax purposes, which items for general accounting
purposes will not be fully reflected in the utility's determination of
annual net income until subsequent years. This subaccount of
190 accounts for the state taxes related to removal costs. For tax
purposes, removal costs are deducted when incurred.
296
190311
Decommissioning-Fed
This account shall be debited and account 411.1, Provision for
Deferred Income Taxes - Credit, Utility Operating Income, or
Account 411.2, Provision for Deferred Income Taxes - Credit,
Other Income and Deductions, as appropriate, shall be credited
with an amount equal to that by which income taxes payable for
the year are higher because of the inclusion of certain items in
income for tax purposes, which items for general accounting
purposes will not be fully reflected in the utility's determination of
annual net income until subsequent years. This subaccount of
190 accounts for the federal taxes related to the decommissioning
fund.
(3)
Account Title
(4)
Account Description
This account shall be debited and account 411.1, Provision for
Deferred Income Taxes - Credit, Utility Operating Income, or
Account 411.2, Provision for Deferred Income Taxes - Credit,
Other Income and Deductions, as appropriate, shall be credited
with an amount equal to that by which income taxes payable for
the year are higher because of the inclusion of certain items in
income for tax purposes, which items for general accounting
purposes will not be fully reflected in the utility's determination of
annual net income until subsequent years. This subaccount of
190 accounts for the federal taxes related to deferred fuel - gas.
This represents the deduction of deferred fuel costs related to
under recoveries of fuel expense and deductions for tax purposes
for over recoveries.
This account shall be debited and account 411.1, Provision for
Deferred Income Taxes - Credit, Utility Operating Income, or
Account 411.2, Provision for Deferred Income Taxes - Credit,
Other Income and Deductions, as appropriate, shall be credited
with an amount equal to that by which income taxes payable for
the year are higher because of the inclusion of certain items in
income for tax purposes, which items for general accounting
purposes will not be fully reflected in the utility's determination of
annual net income until subsequent years. This subaccount of
190 accounts for the state taxes related to deferred fuel - gas.
This represents the deduction of deferred fuel costs related to
under recoveries of fuel expense and deductions for tax purposes
for past over recoveries.
E-9 Page 24 of 99
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41 Schedule E-9
Arkansas Public Service Commission
Chart of Accounts
Minimum Filing Requirements
Partially Projected Test Year Ended
Entergy Arkansas, Inc.
March 31, 2015
Docket No. 15-015-U
(1)
LN
(2)
Account
297
190312
Decommissioning-State
298
190325
Litigation Settlement - Fed
299
190326
Litigation Settlement - State
300
190331
Accrued Medical Claims-Fed
301
190332
Accrued Medical Claims-State
This account shall be debited and account 411.1, Provision for
Deferred Income Taxes - Credit, Utility Operating Income, or
Account 411.2, Provision for Deferred Income Taxes - Credit,
Other Income and Deductions, as appropriate, shall be credited
with an amount equal to that by which income taxes payable for
the year are higher because of the inclusion of certain items in
income for tax purposes, which items for general accounting
purposes will not be fully reflected in the utility's determination of
annual net income until subsequent years. This subaccount of
190 accounts for the state taxes related to accrued medical
claims. This represents the elimination of the book accrual for
these costs which are deductible for tax when actually incurred.
302
190341
Accrued Dues & Contrib-Fed
303
190342
Accrued Dues & Contr-St
304
190351
Uncollect Accts Reserve-Fed
This account represents accumulated deferred income taxes
related to temporary differences for Federal.
This account represents accumulated deferred income taxes
related to temporary differences for State.
This account shall be debited and account 411.1, Provision for
Deferred Income Taxes - Credit, Utility Operating Income, or
Account 411.2, Provision for Deferred Income Taxes - Credit,
Other Income and Deductions, as appropriate, shall be credited
with an amount equal to that by which income taxes payable for
the year are higher because of the inclusion of certain items in
income for tax purposes, which items for general accounting
purposes will not be fully reflected in the utility's determination of
annual net income until subsequent years. This subaccount of
190 accounts for the federal taxes related to the uncollectible
accounts reserve. This represents the difference between the bad
debts written off (determined to be uncollectible) and the provision
booked as a reasonable addition to the reserve for bad debts.
Only those bad debts written off are deductible for tax.
(3)
Account Title
(4)
Account Description
This account shall be debited and account 411.1, Provision for
Deferred Income Taxes - Credit, Utility Operating Income, or
Account 411.2, Provision for Deferred Income Taxes - Credit,
Other Income and Deductions, as appropriate, shall be credited
with an amount equal to that by which income taxes payable for
the year are higher because of the inclusion of certain items in
income for tax purposes, which items for general accounting
purposes will not be fully reflected in the utility's determination of
annual net income until subsequent years. This subaccount of
190 accounts for the state taxes related to the decommissioning
fund.
To record federal accumulated deferred taxes related to litigation
settlements.
To record state accumulated deferred taxes related to litigation
settlements.
This account shall be debited and account 411.1, Provision for
Deferred Income Taxes - Credit, Utility Operating Income, or
Account 411.2, Provision for Deferred Income Taxes - Credit,
Other Income and Deductions, as appropriate, shall be credited
with an amount equal to that by which income taxes payable for
the year are higher because of the inclusion of certain items in
income for tax purposes, which items for general accounting
purposes will not be fully reflected in the utility's determination of
annual net income until subsequent years. This subaccount of
190 accounts for the federal taxes related to accrued medical
claims. This represents the elimination of the book accrual for
these costs which are deductible for tax when actually incurred.
E-9 Page 25 of 99
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41 Schedule E-9
Arkansas Public Service Commission
Chart of Accounts
Minimum Filing Requirements
Partially Projected Test Year Ended
Entergy Arkansas, Inc.
March 31, 2015
Docket No. 15-015-U
(1)
LN
(2)
Account
305
190352
Uncollect Accts Reserve-St
This account shall be debited and account 411.1, Provision for
Deferred Income Taxes - Credit, Utility Operating Income, or
Account 411.2, Provision for Deferred Income Taxes - Credit,
Other Income and Deductions, as appropriate, shall be credited
with an amount equal to that by which income taxes payable for
the year are higher because of the inclusion of certain items in
income for tax purposes, which items for general accounting
purposes will not be fully reflected in the utility's determination of
annual net income until subsequent years. This subaccount of
190 accounts for the state taxes related to the uncollectible
accounts reserve. This represents the difference between the bad
debts written off (determined to be uncollectible) and the provision
booked as a reasonable addition to the reserve for bad debts.
Only those bad debts written off are deductible for tax.
306
190375
Regulatory Liability-Federal
307
190376
Regulatory Liability-State
This account shall be debited and account 411.1, Provision for
Deferred Income Taxes - Credit, Utility Operating Income, or
Account 411.2, Provision for Deferred Income Taxes - Credit,
Other Income and Deductions, as appropriate, shall be credited
with an amount equal to that by which income taxes payable for
the year are higher because of the inclusion of certain items in
income for tax purposes, which items for general accounting
purposes will not be fully reflected in the utility's determination of
annual net income until subsequent years. This subaccount of
190 accounts for the federal taxes representing the elimination of
the book accrual for regulatory liability which is deductible for tax
when actually incurred.
This account shall be debited and account 411.1, Provision for
Deferred Income Taxes - Credit, Utility Operating Income, or
Account 411.2, Provision for Deferred Income Taxes - Credit,
Other Income and Deductions, as appropriate, shall be credited
with an amount equal to that by which income taxes payable for
the year are higher because of the inclusion of certain items in
income for tax purposes, which items for general accounting
purposes will not be fully reflected in the utility's determination of
annual net income until subsequent years. This subaccount of
190 accounts for the state taxes representing the elimination of
the book accrual for the regulatory liability which is deductible for
tax when actually incurred.
308
190381
Partnership Income/Loss - Fed
(3)
Account Title
(4)
Account Description
This account shall be debited and account 411.1, Provision for
Deferred Income Taxes - Credit, Utility Operating Income, or
Account 411.2, Provision for Deferred Income Taxes - Credit,
Other Income and Deductions, as appropriate, shall be credited
with an amount equal to that by which income taxes payable for
the year are higher because of the inclusion of certain items in
income for tax purposes, which items for general accounting
purposes will not be fully reflected in the utility's determination of
annual net income until subsequent years. This subaccount of
190 accounts for the federal taxes related to the timing differences
for partnership income or loss.
E-9 Page 26 of 99
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41 Schedule E-9
Arkansas Public Service Commission
Chart of Accounts
Minimum Filing Requirements
Partially Projected Test Year Ended
Entergy Arkansas, Inc.
March 31, 2015
Docket No. 15-015-U
(1)
LN
(2)
Account
(3)
Account Title
(4)
Account Description
309
190382
Partnership Income/Loss-State
This account shall be debited and account 411.1, Provision for
Deferred Income Taxes - Credit, Utility Operating Income, or
Account 411.2, Provision for Deferred Income Taxes - Credit,
Other Income and Deductions, as appropriate, shall be credited
with an amount equal to that by which income taxes payable for
the year are higher because of the inclusion of certain items in
income for tax purposes, which items for general accounting
purposes will not be fully reflected in the utility's determination of
annual net income until subsequent years. This subaccount of
190 accounts for the state taxes related to the timing differences
for partnership income or loss.
310
190391
Contract Def Revenue-Fed
311
190392
Contract Def Revenue-State
312
190421
Environmental Reserve-Fed
This account shall be debited and account 411.1, Provision for
Deferred Income Taxes - Credit, Utility Operating Income, or
Account 411.2, Provision for Deferred Income Taxes - Credit,
Other Income and Deductions, as appropriate, shall be credited
with an amount equal to that by which income taxes payable for
the year are higher because of the inclusion of certain items in
income for tax purposes, which items for general accounting
purposes will not be fully reflected in the utility's determination of
annual net income until subsequent years. This subaccount of
190 accounts for the federal taxes related to contract deferred
revenue. This represents the elimination of the book accrual for
these payments which are deductible for tax when actually
incurred.
This account shall be debited and account 411.1, Provision for
Deferred Income Taxes - Credit, Utility Operating Income, or
Account 411.2, Provision for Deferred Income Taxes - Credit,
Other Income and Deductions, as appropriate, shall be credited
with an amount equal to that by which income taxes payable for
the year are higher because of the inclusion of certain items in
income for tax purposes, which items for general accounting
purposes will not be fully reflected in the utility's determination of
annual net income until subsequent years. This subaccount of
190 accounts for the state taxes related to contract deferred
revenue. This represents the elimination of the book accrual for
these payments which are deductible for tax when actually
incurred.
This account shall be debited and account 411.1, Provision for
Deferred Income Taxes - Credit, Utility Operating Income, or
Account 411.2, Provision for Deferred Income Taxes - Credit,
Other Income and Deductions, as appropriate, shall be credited
with an amount equal to that by which income taxes payable for
the year are higher because of the inclusion of certain items in
income for tax purposes, which items for general accounting
purposes will not be fully reflected in the utility's determination of
annual net income until subsequent years. This subaccount of
190 accounts for the federal taxes related to the environmental
reserve. This represents the elimination of the book accrual for
these costs which are deductible for tax when actually incurred.
E-9 Page 27 of 99
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41 Schedule E-9
Arkansas Public Service Commission
Chart of Accounts
Minimum Filing Requirements
Partially Projected Test Year Ended
Entergy Arkansas, Inc.
March 31, 2015
Docket No. 15-015-U
(1)
LN
(2)
Account
313
190422
Environmental Reserve-State
This account shall be debited and account 411.1, Provision for
Deferred Income Taxes - Credit, Utility Operating Income, or
Account 411.2, Provision for Deferred Income Taxes - Credit,
Other Income and Deductions, as appropriate, shall be credited
with an amount equal to that by which income taxes payable for
the year are higher because of the inclusion of certain items in
income for tax purposes, which items for general accounting
purposes will not be fully reflected in the utility's determination of
annual net income until subsequent years. This subaccount of
190 accounts for the state taxes related to the environmental
reserve. This represents the elimination of the book accrual for
these costs which are deductible for tax when actually incurred.
314
190427
Mark to Market-Oth Contrac-Fed
315
190428
Mark to Market-Oth Contract-St
316
190451
Incentive-Fed
317
190452
Incentive-State
318
190455
Teamshr Over/Under Accrual-Fed
This account is for federal deferred taxes related to Mark to
Market adjustment on other contracts .
This account is for state deferred taxes related to Mark to Market
adjustment on other contracts .
This account shall be debited and account 411.1, Provision for
Deferred Income Taxes - Credit, Utility Operating Income, or
Account 411.2, Provision for Deferred Income Taxes - Credit,
Other Income and Deductions, as appropriate, shall be credited
with an amount equal to that by which income taxes payable for
the year are higher because of the inclusion of certain items in
income for tax purposes, which items for general accounting
purposes will not be fully reflected in the utility's determination of
annual net income until subsequent years. This subaccount of
190 accounts for the federal taxes related to incentive
compensation. This represents the elimination of the book
accrual for these costs which are deductible for tax when actually
incurred.
This account shall be debited and account 411.1, Provision for
Deferred Income Taxes - Credit, Utility Operating Income, or
Account 411.2, Provision for Deferred Income Taxes - Credit,
Other Income and Deductions, as appropriate, shall be credited
with an amount equal to that by which income taxes payable for
the year are higher because of the inclusion of certain items in
income for tax purposes, which items for general accounting
purposes will not be fully reflected in the utility's determination of
annual net income until subsequent years. This subaccount of
190 accounts for the state taxes related to incentive
compensation. This represents the elimination of the book
accrual for these costs which are deductible for tax when actually
incurred.
This account shall be debited and account 411.1, Provision for
Deferred Income Taxes - Credit, Utility Operating Income, or
Account 411.2, Provision for Deferred Income Taxes - Credit,
Other Income and Deductions, as appropriate, shall be credited
with an amount equal to that by which income taxes payable for
the year are higher because of the inclusion of certain items in
income for tax purposes, which items for general accounting
purposes will not be fully reflected in the utility's determination of
annual net income until subsequent years. This subaccount of
190 accounts for the federal taxes related to the teamsharing
over/under accrual. It is used to record the difference between
the teamsharing accrual and payments.
(3)
Account Title
(4)
Account Description
E-9 Page 28 of 99
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41 Schedule E-9
Arkansas Public Service Commission
Chart of Accounts
Minimum Filing Requirements
Partially Projected Test Year Ended
Entergy Arkansas, Inc.
March 31, 2015
Docket No. 15-015-U
(1)
LN
(2)
Account
319
190456
Teamshr Over/Undr Accrual-Stat
This account shall be debited and account 411.1, Provision for
Deferred Income Taxes - Credit, Utility Operating Income, or
Account 411.2, Provision for Deferred Income Taxes - Credit,
Other Income and Deductions, as appropriate, shall be credited
with an amount equal to that by which income taxes payable for
the year are higher because of the inclusion of certain items in
income for tax purposes, which items for general accounting
purposes will not be fully reflected in the utility's determination of
annual net income until subsequent years. This subaccount of
190 accounts for the state taxes related to the teamsharing
over/under accrual. It is used to record the difference between
the teamsharing accrual and payments.
320
190461
Sale-Coal Handling Equip-Fed
321
190462
Sale-Coal Handling Equip-St
322
190463
Bldg S/L Tax Gain-Fed
323
190464
Bldg S/L Tax Gain-State
324
190465
Ano Bldg Sale-Fed
325
190466
Ano Bldg Sale-State
This account shall be debited and account 411.1, Provision for
Deferred Income Taxes - Credit, Utility Operating Income, or
Account 411.2, Provision for Deferred Income Taxes - Credit,
Other Income and Deductions, as appropriate, shall be credited
with an amount equal to that by which income taxes payable for
the year are higher because of the inclusion of certain items in
income for tax purposes, which items for general accounting
purposes will not be fully reflected in the utility's determination of
annual net income until subsequent years. This subaccount of
190 accounts for the federal taxes related to the sale of coal
handling equipment.
This account shall be debited and account 411.1, Provision for
Deferred Income Taxes - Credit, Utility Operating Income, or
Account 411.2, Provision for Deferred Income Taxes - Credit,
Other Income and Deductions, as appropriate, shall be credited
with an amount equal to that by which income taxes payable for
the year are higher because of the inclusion of certain items in
income for tax purposes, which items for general accounting
purposes will not be fully reflected in the utility's determination of
annual net income until subsequent years. This subaccount of
190 accounts for the state taxes related to the sale of coal
handling equipment.
This account is for federal accumulated deferred income taxes on
temporary differences.
This account is for State accumulated deferred income taxes on
temporary differences.
This account shall be debited and account 411.1, Provision for
Deferred Income Taxes - Credit, Utility Operating Income, or
Account 411.2, Provision for Deferred Income Taxes - Credit,
Other Income and Deductions, as appropriate, shall be credited
with an amount equal to that by which income taxes payable for
the year are higher because of the inclusion of certain items in
income for tax purposes, which items for general accounting
purposes will not be fully reflected in the utility's determination of
annual net income until subsequent years. This subaccount of
190 accounts for the federal taxes related to the ANO building
sale.
This account shall be debited and account 411.1, Provision for
Deferred Income Taxes - Credit, Utility Operating Income, or
Account 411.2, Provision for Deferred Income Taxes - Credit,
Other Income and Deductions, as appropriate, shall be credited
with an amount equal to that by which income taxes payable for
the year are higher because of the inclusion of certain items in
income for tax purposes, which items for general accounting
purposes will not be fully reflected in the utility's determination of
annual net income until subsequent years. This subaccount of
190 accounts for the state taxes related to the ANO building sale.
(3)
Account Title
(4)
Account Description
E-9 Page 29 of 99
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41 Schedule E-9
Arkansas Public Service Commission
Chart of Accounts
Minimum Filing Requirements
Partially Projected Test Year Ended
Entergy Arkansas, Inc.
March 31, 2015
Docket No. 15-015-U
(1)
LN
(2)
Account
(3)
Account Title
326
190513
Entergy Stck Invstmnt Plan-Fed
327
190514
Entergy Stock Invstmnt Plan-St
328
190517
Long-Term Incentive Comp-Feder
329
190518
Long-Term Incentive Comp-State
330
190519
Stock Options - Federal
(4)
Account Description
This account shall be debited and account 411.1, Provision for
Deferred Income Taxes - Credit, Utility Operating Income, or
Account 411.2, Provision for Deferred Income Taxes - Credit,
Other Income and Deductions, as appropriate, shall be credited
with an amount equal to that by which income taxes payable for
the year are higher because of the inclusion of certain items in
income for tax purposes, which items for general accounting
purposes will not be fully reflected in the utility's determination of
annual net income until subsequent years. This subaccount of
190 accounts for the federal taxes related to the Entergy Stock
Investment Plan.
This account shall be debited and account 411.1, Provision for
Deferred Income Taxes - Credit, Utility Operating Income, or
Account 411.2, Provision for Deferred Income Taxes - Credit,
Other Income and Deductions, as appropriate, shall be credited
with an amount equal to that by which income taxes payable for
the year are higher because of the inclusion of certain items in
income for tax purposes, which items for general accounting
purposes will not be fully reflected in the utility's determination of
annual net income until subsequent years. This subaccount of
190 accounts for the state taxes related to the Entergy Stock
Investment Plan.
This account shall be debited and account 411.1, Provision for
Deferred Income Taxes - Credit, Utility Operating Income, or
Account 411.2, Provision for Deferred Income Taxes - Credit,
Other Income and Deductions, as appropriate, shall be credited
with an amount equal to that by which income taxes payable for
the year are higher because of the inclusion of certain items in
income for tax purposes, which items for general accounting
purposes will not be fully reflected in the utility's determination of
annual net income until subsequent years. This subaccount of
190 accounts for the federal taxes related to long-term incentive
compensation. This represents the elimination of the book
accrual for these costs which are deductible for tax when actually
incurred.
This account shall be debited and account 411.1, Provision for
Deferred Income Taxes - Credit, Utility Operating Income, or
Account 411.2, Provision for Deferred Income Taxes - Credit,
Other Income and Deductions, as appropriate, shall be credited
with an amount equal to that by which income taxes payable for
the year are higher because of the inclusion of certain items in
income for tax purposes, which items for general accounting
purposes will not be fully reflected in the utility's determination of
annual net income until subsequent years. This subaccount of
190 accounts for the state taxes related to long-term incentive
compensation. This represents the elimination of the book
accrual for these costs which are deductible for tax when actually
incurred.
This account shall be debited and account 411.1, Provision for
Deferred Income Taxes - Credit, Utility Operating Income, or
Account 411.2, Provision for Deferred Income Taxes - Credit,
Other Income and Deductions, as appropriate, shall be credited
with an amount equal to that by which income taxes payable for
the year are higher because of the inclusion of certain items in
income for tax purposes, which items for general accounting
purposes will not be fully reflected in the utility's determination of
annual net income until subsequent years. This subaccount of
190 accounts for the federal taxes related to stock options. This
represents the difference between the market value of post 2002
options on the date exercised and the option price when granted.
This difference is compensation to the employee.
E-9 Page 30 of 99
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41 Schedule E-9
Arkansas Public Service Commission
Chart of Accounts
Minimum Filing Requirements
Partially Projected Test Year Ended
Entergy Arkansas, Inc.
March 31, 2015
Docket No. 15-015-U
(1)
LN
(2)
Account
331
190520
Stock Options - State
This account shall be debited and account 411.1, Provision for
Deferred Income Taxes - Credit, Utility Operating Income, or
Account 411.2, Provision for Deferred Income Taxes - Credit,
Other Income and Deductions, as appropriate, shall be credited
with an amount equal to that by which income taxes payable for
the year are higher because of the inclusion of certain items in
income for tax purposes, which items for general accounting
purposes will not be fully reflected in the utility's determination of
annual net income until subsequent years. This subaccount of
190 accounts for the state taxes related to stock options. This
represents the difference between the market value of post 2002
options on the date exercised and the option price when granted.
This difference is compensation to the employee.
332
190523
Stock Options Exercised-Fed
333
190524
Stock Options Excerised-St
334
190525
Restricted Stock Awards-Fed
This account shall be debited and account 411.1, Provision for
Deferred Income Taxes - Credit, Utility Operating Income, or
Account 411.2, Provision for Deferred Income Taxes - Credit,
Other Income and Deductions, as appropriate, shall be credited
with an amount equal to that by which income taxes payable for
the year are higher because of the inclusion of certain items in
income for tax purposes, which items for general accounting
purposes will not be fully reflected in the utility's determination of
annual net income until subsequent years. This subaccount of
190 accounts for the federal taxes related to stock options
exercised. This represents the difference between the market
value of pre 2003 options on the date exercised and the option
price when granted. This difference is compensation to the
employee.
This account shall be debited and account 411.1, Provision for
Deferred Income Taxes - Credit, Utility Operating Income, or
Account 411.2, Provision for Deferred Income Taxes - Credit,
Other Income and Deductions, as appropriate, shall be credited
with an amount equal to that by which income taxes payable for
the year are higher because of the inclusion of certain items in
income for tax purposes, which items for general accounting
purposes will not be fully reflected in the utility's determination of
annual net income until subsequent years. This subaccount of
190 accounts for the state taxes related to stock options
exercised. This represents the difference between the market
value of pre 2003 options on the date exercised and the option
price when granted. This difference is compensation to the
employee.
This account shall be debited and account 411.1, Provision for
Deferred Income Taxes - Credit, Utility Operating Income, or
Account 411.2, Provision for Deferred Income Taxes - Credit,
Other Income and Deductions, as appropriate, shall be credited
with an amount equal to that by which income taxes payable for
the year are higher because of the inclusion of certain items in
income for tax purposes, which items for general accounting
purposes will not be fully reflected in the utility's determination of
annual net income until subsequent years. This subaccount of
190 accounts for the federal taxes related to restricted stock
awards. This represents the difference between the deduction
incurred for tax and the accrued compensation to the employee
for restricted stock awards.
(3)
Account Title
(4)
Account Description
E-9 Page 31 of 99
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41 Schedule E-9
Arkansas Public Service Commission
Chart of Accounts
Minimum Filing Requirements
Partially Projected Test Year Ended
Entergy Arkansas, Inc.
March 31, 2015
Docket No. 15-015-U
(1)
LN
(2)
Account
335
190526
Restricted Stock Awards-State
This account shall be debited and account 411.1, Provision for
Deferred Income Taxes - Credit, Utility Operating Income, or
Account 411.2, Provision for Deferred Income Taxes - Credit,
Other Income and Deductions, as appropriate, shall be credited
with an amount equal to that by which income taxes payable for
the year are higher because of the inclusion of certain items in
income for tax purposes, which items for general accounting
purposes will not be fully reflected in the utility's determination of
annual net income until subsequent years. This subaccount of
190 accounts for the state taxes related to restricted stock
awards. This represents the difference between the deduction
incurred for tax and the accrued compensation to the employee
for restricted stock awards.
336
190531
Deferred Director'S Fees-Fed
337
190532
Deferred Director'S Fees-St
This account shall be debited and account 411.1, Provision for
Deferred Income Taxes - Credit, Utility Operating Income, or
Account 411.2, Provision for Deferred Income Taxes - Credit,
Other Income and Deductions, as appropriate, shall be credited
with an amount equal to that by which income taxes payable for
the year are higher because of the inclusion of certain items in
income for tax purposes, which items for general accounting
purposes will not be fully reflected in the utility's determination of
annual net income until subsequent years. This subaccount of
190 accounts for the federal taxes related to deferred directors'
fees.
This account shall be debited and account 411.1, Provision for
Deferred Income Taxes - Credit, Utility Operating Income, or
Account 411.2, Provision for Deferred Income Taxes - Credit,
Other Income and Deductions, as appropriate, shall be credited
with an amount equal to that by which income taxes payable for
the year are higher because of the inclusion of certain items in
income for tax purposes, which items for general accounting
purposes will not be fully reflected in the utility's determination of
annual net income until subsequent years. This subaccount of
190 accounts for the state taxes related to deferred directors' fees.
338
190603
Rate Refund-Federal
This account shall be debited and account 411.1, Provision for
Deferred Income Taxes - Credit, Utility Operating Income, or
Account 411.2, Provision for Deferred Income Taxes - Credit,
Other Income and Deductions, as appropriate, shall be credited
with an amount equal to that by which income taxes payable for
the year are higher because of the inclusion of certain items in
income for tax purposes, which items for general accounting
purposes will not be fully reflected in the utility's determination of
annual net income until subsequent years. This subaccount of
190 accounts for the federal taxes related to rate refunds. This
represents the elimination of the book accrual for these costs
which are deductible for tax when actually incurred.
339
190604
Rate Refund-State
This account shall be debited and account 411.1, Provision for
Deferred Income Taxes - Credit, Utility Operating Income, or
Account 411.2, Provision for Deferred Income Taxes - Credit,
Other Income and Deductions, as appropriate, shall be credited
with an amount equal to that by which income taxes payable for
the year are higher because of the inclusion of certain items in
income for tax purposes, which items for general accounting
purposes will not be fully reflected in the utility's determination of
annual net income until subsequent years. This subaccount of
190 accounts for the state taxes related to rate refunds. This
represents the elimination of the book accrual for these costs
which are deductible for tax when actually incurred.
(3)
Account Title
(4)
Account Description
E-9 Page 32 of 99
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41 Schedule E-9
Arkansas Public Service Commission
Chart of Accounts
Minimum Filing Requirements
Partially Projected Test Year Ended
Entergy Arkansas, Inc.
March 31, 2015
Docket No. 15-015-U
(1)
LN
(2)
Account
340
190609
Sale Of Epa Allowances - Fed
341
190610
Sale Of Epa Allowances - St
342
190613
Severance Accrual - Federal
343
190614
Severance Accrual - State
344
190615
AP Accruals Federal
345
190616
AP Accruals - State
346
190641
Re-Organization Costs-Federal
(3)
Account Title
(4)
Account Description
This account shall be debited and account 411.1, Provision for
Deferred Income Taxes - Credit, Utility Operating Income, or
Account 411.2, Provision for Deferred Income Taxes - Credit,
Other Income and Deductions, as appropriate, shall be credited
with an amount equal to that by which income taxes payable for
the year are higher because of the inclusion of certain items in
income for tax purposes, which items for general accounting
purposes will not be fully reflected in the utility's determination of
annual net income until subsequent years. This subaccount of
190 accounts for the federal taxes related to the sale of EPA
allowances.
This account shall be debited and account 411.1, Provision for
Deferred Income Taxes - Credit, Utility Operating Income, or
Account 411.2, Provision for Deferred Income Taxes - Credit,
Other Income and Deductions, as appropriate, shall be credited
with an amount equal to that by which income taxes payable for
the year are higher because of the inclusion of certain items in
income for tax purposes, which items for general accounting
purposes will not be fully reflected in the utility's determination of
annual net income until subsequent years. This subaccount of
190 accounts for the state taxes related to the sale of EPA
allowances.
This subaccount of 190 accounts for the federal taxes related to
the severance accrual.
This subaccount of 190 accounts for the state taxes related to the
severance accrual.
This account shall be debited and account 411.1, Provision for
Deferred Income Taxes - Credit, Utility Operating Income, or
Account 411.2, Provision for Deferred Income Taxes - Credit,
Other Income and Deductions, as appropriate, shall be credited
with an amount equal to that by which income taxes payable for
the year are higher because of the inclusion of certain items in
income for tax purposes, which items for general accounting
purposes will not be fully reflected in the utility's determination of
annual net income until subsequent years. This subaccount of
190 accounts for the federal taxes related to accounts payables
accruals.
This account shall be debited and account 411.1, Provision for
Deferred Income Taxes - Credit, Utility Operating Income, or
Account 411.2, Provision for Deferred Income Taxes - Credit,
Other Income and Deductions, as appropriate, shall be credited
with an amount equal to that by which income taxes payable for
the year are higher because of the inclusion of certain items in
income for tax purposes, which items for general accounting
purposes will not be fully reflected in the utility's determination of
annual net income until subsequent years. This subaccount of
190 accounts for the state taxes related to accounts payables
accruals.
This account shall be debited and account 411.1, Provision for
Deferred Income Taxes - Credit, Utility Operating Income, or
Account 411.2, Provision for Deferred Income Taxes - Credit,
Other Income and Deductions, as appropriate, shall be credited
with an amount equal to that by which income taxes payable for
the year are higher because of the inclusion of certain items in
income for tax purposes, which items for general accounting
purposes will not be fully reflected in the utility's determination of
annual net income until subsequent years. This subaccount of
190 accounts for the federal taxes related to reorganization costs.
E-9 Page 33 of 99
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41 Schedule E-9
Arkansas Public Service Commission
Chart of Accounts
Minimum Filing Requirements
Partially Projected Test Year Ended
Entergy Arkansas, Inc.
March 31, 2015
Docket No. 15-015-U
(1)
LN
(2)
Account
347
190642
Re-Organization Costs - State
This account shall be debited and account 411.1, Provision for
Deferred Income Taxes - Credit, Utility Operating Income, or
Account 411.2, Provision for Deferred Income Taxes - Credit,
Other Income and Deductions, as appropriate, shall be credited
with an amount equal to that by which income taxes payable for
the year are higher because of the inclusion of certain items in
income for tax purposes, which items for general accounting
purposes will not be fully reflected in the utility's determination of
annual net income until subsequent years. This subaccount of
190 accounts for the state taxes related to reorganization costs.
348
190701
Fas 109 Adjustment - Fed
This account shall be debited and account 411.1, Provision for
Deferred Income Taxes - Credit, Utility Operating Income, or
Account 411.2, Provision for Deferred Income Taxes - Credit,
Other Income and Deductions, as appropriate, shall be credited
with an amount equal to that by which income taxes payable for
the year are higher because of the inclusion of certain items in
income for tax purposes, which items for general accounting
purposes will not be fully reflected in the utility's determination of
annual net income until subsequent years. This subaccount of
190 accounts for the federal taxes related to the Statement of
Financial Accounting Standards (SFAS) 109 adjustment. This
represents additional deferred taxes on temporary differences due
to implementation and restatement for SFAS No. 109.
349
190702
Fas 109 Adjustment - State
This account shall be debited and account 411.1, Provision for
Deferred Income Taxes - Credit, Utility Operating Income, or
Account 411.2, Provision for Deferred Income Taxes - Credit,
Other Income and Deductions, as appropriate, shall be credited
with an amount equal to that by which income taxes payable for
the year are higher because of the inclusion of certain items in
income for tax purposes, which items for general accounting
purposes will not be fully reflected in the utility's determination of
annual net income until subsequent years. This subaccount of
190 accounts for the state taxes related to the Statement of
Financial Accounting Standards (SFAS) 109 adjustment. This
represents additional deferred taxes on temporary differences due
to implementation and restatement for SFAS No. 109.
350
190881
ADIT-NOL C/F-TAP-FED - Current
This account shall be debited and account 411.1, Provision for
Deferred Income Taxes - Credit, Utility Operating Income, or
Account 411.2, Provision for Deferred Income Taxes - Credit,
Other Income and Deductions, as appropriate, shall be credited
with an amount equal to that by which income taxes payable for
the year are higher because of the inclusion of certain items in
income for tax purposes, which items for general accounting
purposes will not be fully reflected in the utility's determination of
annual net income until subsequent years. This subaccount of
190 represents the net change in the utilization or generation of
net operating loss carryforwards, which are tax deductions in
excess of taxable income. This account contains the current
portion of the Federal net operating loss.
(3)
Account Title
(4)
Account Description
E-9 Page 34 of 99
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41 Schedule E-9
Arkansas Public Service Commission
Chart of Accounts
Minimum Filing Requirements
Partially Projected Test Year Ended
Entergy Arkansas, Inc.
March 31, 2015
Docket No. 15-015-U
(1)
LN
(2)
Account
351
190882
Adit-Nol C/F - State-Current
This account shall be debited and account 411.1, Provision for
Deferred Income Taxes - Credit, Utility Operating Income, or
Account 411.2, Provision for Deferred Income Taxes - Credit,
Other Income and Deductions, as appropriate, shall be credited
with an amount equal to that by which income taxes payable for
the year are higher because of the inclusion of certain items in
income for tax purposes, which items for general accounting
purposes will not be fully reflected in the utility's determination of
annual net income until subsequent years. This subaccount of
190 represents the net change in the utilization or generation of
net operating loss carryforwards, which are tax deductions in
excess of taxable income. This account contains the current
portion of the state net operating loss.
352
190883
ADIT-Contribution C/F-TAP-FED
353
190884
ADIT-Tax CR C/F-TAP-FED
354
190886
ADIT-AMT CR C/F-TAP-FED
This account shall be debited and account 411.1, Provision for
Deferred Income Taxes - Credit, Utility Operating Income, or
Account 411.2, Provision for Deferred Income Taxes - Credit,
Other Income and Deductions, as appropriate, shall be credited
with an amount equal to that by which income taxes payable for
the year are higher because of the inclusion of certain items in
income for tax purposes, which items for general accounting
purposes will not be fully reflected in the utility's determination of
annual net income until subsequent years. This subaccount of
190 accounts for the carryforward of charitable contributions not
used on the federal tax return.
This account shall be debited and account 411.1, Provision for
Deferred Income Taxes - Credit, Utility Operating Income, or
Account 411.2, Provision for Deferred Income Taxes - Credit,
Other Income and Deductions, as appropriate, shall be credited
with an amount equal to that by which income taxes payable for
the year are higher because of the inclusion of certain items in
income for tax purposes, which items for general accounting
purposes will not be fully reflected in the utility's determination of
annual net income until subsequent years. This subaccount of
190 accounts for the carryforward of a federal income tax credit
that has been recognized but not utilized on the federal income
tax return.
This account shall be debited and account 411.1, Provision for
Deferred Income Taxes - Credit, Utility Operating Income, or
Account 411.2, Provision for Deferred Income Taxes - Credit,
Other Income and Deductions, as appropriate, shall be credited
with an amount equal to that by which income taxes payable for
the year are higher because of the inclusion of certain items in
income for tax purposes, which items for general accounting
purposes will not be fully reflected in the utility's determination of
annual net income until subsequent years. This subaccount of
190 accounts for the carryforward of a federal income tax credit
for alternative minumum tax paid that has been recognized but
not utilized on the federal income tax return.
355
190887
FED ADIT on State Tax Accrual
(3)
Account Title
(4)
Account Description
This account shall be debited and account 411.1, Provision for
Deferred Income Taxes - Credit, Utility Operating Income, or
Account 411.2, Provision for Deferred Income Taxes - Credit,
Other Income and Deductions, as appropriate, shall be credited
with an amount equal to that by which income taxes payable for
the year are higher because of the inclusion of certain items in
income for tax purposes, which items for general accounting
purposes will not be fully reflected in the utility's determination of
annual net income until subsequent years. This subaccount of
190 accounts for the federal deferred income taxes on state
income tax accrued but not yet deducted on the federal return.
E-9 Page 35 of 99
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41 Schedule E-9
Arkansas Public Service Commission
Chart of Accounts
Minimum Filing Requirements
Partially Projected Test Year Ended
Entergy Arkansas, Inc.
March 31, 2015
Docket No. 15-015-U
(1)
LN
(2)
Account
(3)
Account Title
356
190981
Fed Offset-State Cur Carryover
357
190983
ADIT-NOL C/F TAP-Fed-Non-curr
358
190986
ADIT-Contrib C/F St Non-Cur
This account shall be debited and account 411.1, Provision for
Deferred Income Taxes - Credit, Utility Operating Income, or
Account 411.2, Provision for Deferred Income Taxes - Credit,
Other Income and Deductions, as appropriate, shall be credited
with an amount equal to that by which income taxes payable for
the year are higher because of the inclusion of certain items in
income for tax purposes, which items for general accounting
purposes will not be fully reflected in the utility's determination of
annual net income until subsequent years. This subaccount of
190 accounts is for the carryforward of charitable contributions not
used on the state income tax return.
359
190F49
FIN 48 Contra NOL
360
190P51
ADIT-Ben-Potnt Disall UTPs Res
361
190X01
ADIT Fed Current Asset Reclass
362
190X02
ADIT- ST current asset reclass
This account is no longer used. It has been replaced with Accts
236FCO, 236FNO, and 236SCO. Descriptions for these new
accounts are included below.
To record federal accumulated deferred taxes related to the
capture of the indirect federal benefit of permanent uncertain tax
positions.
Accounts ending in "X01", "X02", "X03", and "X04" were created
for the sole purpose of being able to journalize certain balance
sheet statement reclassifications into the general ledger. These
accounts do not contain any original operational transactions.
They are simply used to modify the balance sheet statement line
item presentations in our internally generated balance sheet
statements.
Accounts ending in "X01", "X02", "X03", and "X04" were created
for the sole purpose of being able to journalize certain balance
sheet statement reclassifications into the general ledger. These
accounts do not contain any original operational transactions.
They are simply used to modify the balance sheet statement line
item presentations in our internally generated balance sheet
statements.
363
Liabilities and Other Credits
364
Proprietary Capital
365
201000
Common Stock Issued
(4)
Account Description
To record federal deferred tax offsets on current state tax
attributes per the tax allocation program.
This account shall be debited and account 411.1, Provision for
Deferred Income Taxes - Credit, Utility Operating Income, or
Account 411.2, Provision for Deferred Income Taxes - Credit,
Other Income and Deductions, as appropriate, shall be credited
with an amount equal to that by which income taxes payable for
the year are higher because of the inclusion of certain items in
income for tax purposes, which items for general accounting
purposes will not be fully reflected in the utility's determination of
annual net income until subsequent years. This subaccount of
190 accounts for non-current portion of the federal net operating
loss. The federal net opertating loss carryforwards are tax
deductions in excess of taxable income.
These accounts shall include the par value or the stated value of
stock without par value if such stock has a stated value, and, if
not, the cash value of the consideration received for such nonpar
stock, of each class of capital stock actually issued, including the
par or stated value of such capital stock in account 124, Other
Investments, and account 217, Reacquired Capital Stock.
E-9 Page 36 of 99
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41 Schedule E-9
Arkansas Public Service Commission
Chart of Accounts
Minimum Filing Requirements
Partially Projected Test Year Ended
Entergy Arkansas, Inc.
March 31, 2015
Docket No. 15-015-U
(1)
LN
(2)
Account
366
204000
Preferred Stock Issued
These accounts shall include the par value or the stated value of
stock without par value if such stock has a stated value, and, if
not, the cash value of the consideration received for such nonpar
stock, of each class of capital stock actually issued, including the
par or stated value of such capital stock in account 124, Other
Investments, and account 217, Reacquired Capital Stock.
367
204999
Prefrd Stck Issued W/Sink Fund
368
20499P
Pref St w/S.F. Redeemed (CPD)
369
204CPD
Pref Stock Redeemed (CPD)
370
204CRD
Preferred Stock Issued (CRD)
371
207000
Premium On Capital Stock
Subaccount of 204000 set up for Preferred Stock with Sinking
Fund.
Preferred Stock with Sinking Fund (204999) redeemed. This
account was set up to facilitate the automation of the cash flow
statement.
Preferred Stock (204000) redeemed. This account was set up to
facilitate the automation of the cash flow statement.
Preferred Stock (204000) issued. This account was set up to
facilitate the automation of the cash flow statement.
This account shall include, in a separate subdivision for each
class and series of stock, the excess of the actual cash value of
the consideration received on original issues of capital stock over
the par or stated value and accrued dividends of such stock,
together with assessments against stockholders representing
payments required in excess of par or stated values.
372
207001
Prem Cap Stk-Common
This account shall include, in a separate subdivision for each
class and series of stock, the excess of the actual cash value of
the consideration received on original issues of capital stock over
the par or stated value and accrued dividends of such stock,
together with assessments against stockholders representing
payments required in excess of par or stated values.
373
207002
Prem Cap Stk-Preferred
374
207806
PIC - Restricted Stock Awards
375
207807
PIC - LTIP
376
209000
Reduction In Value Capital St
377
210000
Gain Resale Canc Reacq. Stock
378
214000
Capital Stock Expense
The balance consists of the premium on capital stock-Preferred
for EAI.
Account will be used to track ETR's paid-in-capital activity related
to the Restricted Stock Award incentive program implemented in
2011.
Account will be used to track ETR’s paid-in-capital activity related
to the Long-Term Incentive Plans which became equity based
beginning with the 2012-2014 plan.
This account shall include the balance of credits arising from a
reduction in the par or stated value of capital stock.
This account shall include the balance of credits arising from the
resale or cancellation of reacquired capital stock.
This account shall include in a separate subdivision for each class
and series of stock all commissions and expenses incurred in
connection with the original issuance and sale of capital stock,
including additional capital stock of a particular class or series as
well as first issues. Expenses applicable to capital stock shall not
be deducted from premium on capital stock.
379
214001
Capital Stock Expense-Common
This account shall include in a separate subdivision for each class
and series of stock all commissions and expenses incurred in
connection with the original issuance and sale of capital stock,
including additional capital stock of a particular class or series as
well as first issues. Expenses applicable to capital stock shall not
be deducted from premium on capital stock.
380
214CPD
Capital Stock Expense (CPD)
381
216000
Unappropriated Retained Earn.
This account records Capital Stock Expense-Common (214001)
redeemed. This account was set up to facilitate the automation of
the cash flow statement.
This account shall include the balances, either debit or credit, of
unappropriated retained earnings arising from earnings of the
utility.
(3)
Account Title
(4)
Account Description
E-9 Page 37 of 99
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41 Schedule E-9
Arkansas Public Service Commission
Chart of Accounts
Minimum Filing Requirements
Partially Projected Test Year Ended
Entergy Arkansas, Inc.
March 31, 2015
Docket No. 15-015-U
(1)
LN
(2)
Account
(3)
Account Title
382
216110
Unapp.Undist.Ret.Earn.Arklaho
383
216189
Retained earnings - dividends
384
(4)
Account Description
This account represents Entergy Arkansas' 47.6% ownership
share of unappropriated retained earnings of The Arklahoma
Corporation. Balance will fluctuate based upon earnings or losses
of The Arklahoma Corp.
This account is used in the elimination process. Dividend declared
account 438000 closes out to this account 216189 in the year end
close out process.
Long-Term Debt
385
221000
Bonds
386
221999
Currently Maturing Bonds
387
2219CP
Current Maturing bonds retired
388
2219CR
Currently MaturingBonds Issued
389
221CPD
Bonds retired (CPD)
This account shall include in a separate subdivision for each class
and series of bonds the face value of the actually issued and
unmatured bonds which have not been retired or canceled; also
the face value of such bonds issued by others the payment of
which has been assumed by the utility.
This account includes bonds (as defined in Account 221000)
which are expected to mature within the next 12 months and
which have not been retired or canceled.
This account includes currently maturing bonds (221999) retired
(CP). This account was set up to facilitate the automation of the
cash flow statement.
This account includes currently maturing bonds (221999) issued
(CR). This account was set up to facilitate the automation of the
cash flow statement.
This account includes bonds (221000) retired (CP). This account
was set up to facilitate the automation of the cash flow statement.
390
221CRD
Bonds Issued (CRD)
391
221X08
Retirement of LTD-CF Reclass
392
224000
Other Long Term Debt
393
224300
L.T. Credit Borrowings
394
224999
Currently Maturing Other Ltd
395
2249CP
Current Maturing Otr LTD retir
396
2249CR
CurrentlyMaturingOT-LTD Issued
397
224AFB
Other LTD - LR Air Force Base
This account includes bonds (221000) issued (CR). This account
was set up to facilitate the automation of the cash flow statement.
Accounts ending in "X06", "X07, "X08", and "X09" were created for
the sole purpose of being able to journalize certain cash flow
statement reclassifications into the general ledger. These
accounts do not contain any original operational transactions.
They are simply used to modify cash flow statement line item
presentations in Entergy's internally generated cash flow
statements.
This account shall include, until maturity all long-term debt not
otherwise provided for. This covers such items as receivers'
certificates, real estate mortgages executed or assumed,
assessments for public improvements, notes and unsecured
certificates of indebtedness not owned by associated companies,
receipts outstanding for long-term debt, and other obligations
maturing more than one year from date of issue or assumption.
This account represents the principle balance on various bank
lines of credit.
This account includes Other Long Term Debt (as defined in
Account 224000) which is expected to mature within the next 12
months and which have not been retired or canceled.
This account includes currently maturing other long term debt
(224999) retired (CP). This account was set up to facilitate the
automation of the cash flow statement.
This account includes currently maturing other long-term debt
(224999) issued (CR). This account was set up to facilitate the
automation of the cash flow statement.
Account used to track the long term debt associated with the
acquisition of the Little Rock Air Force Base distribution facilities.
E-9 Page 38 of 99
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41 Schedule E-9
Arkansas Public Service Commission
Chart of Accounts
Minimum Filing Requirements
Partially Projected Test Year Ended
Entergy Arkansas, Inc.
March 31, 2015
Docket No. 15-015-U
(1)
LN
(2)
Account
398
224CPD
Other LTD Retired (CPD)
399
224CRD
Other L. T. Debt Issued (CRD)
400
225000
Unamortized Premium On Debt
401
226000
Unamortized Disc On L-T Debt
402
226CPD
Unamort discount-LTD (CPD)
403
(3)
Account Title
(4)
Account Description
This account includes Other Long Term Debt (as defined in
Account 224000) which is expected to mature within the next 12
months and which have not been retired or canceled. This
account was set up to facilitate the automation of the cash flow
statement.
This account includes other long-term debt (224999) issued (CR).
This account was set up to facilitate the automation of the cash
flow statement.
This account shall include the excess of the cash value of
consideration received over the face value upon the issuance or
assumption of long-term debt securities.
This account shall include the excess of the face value of longterm debt securities over the cash value of consideration received
therefor, related to the issue or assumption of all types and
classes of debt. Amounts recorded in this account shall be
amortized over the life of the respective issues under a plan which
will distribute the amount equitably over the life of the securities.
The amortization shall be on a monthly basis, with the amounts
thereof charged to account 428, Amortization of Debt Discount
and Expense.
This account includes unamortized discount on Long Term Debt
(as defined in Account 226000). This account was set up to
facilitate the automation of the cash flow statement.
Other Noncurrent Liabilities
404
227102
Nuclear Fuel Lease-Non-Curren
405
227103
Misc Capital Lease-Non-Curren
406
2271CR
N. F. Lease-Noncurrent (CRD)
407
228100
Accum Prov For Prop Insurance
408
228101
Int on Accum Prov for Prop Ins
409
228102
EAI 2009 Ice Storm Non-Retail
410
228151
Insurance proceeds-O&M
411
2281FR
Propety ins. prov. reclass
The 1206, 227, and 243205 accounts capture the nuclear fuel
under lease. The balance in this account is offset by the sum of
the non-current and current payable to River Fuel Trust.
To record monthly reduction to lease asset. This will include the
portion not due within one year, of the obligations recorded for
amounts applicable to leased property recorded as assets in
account 1011.
The 1206, 227, and 243205 accounts capture the nuclear fuel
under lease. The balance in this account is offset by the sum of
the non-current and current payable to River Fuel Trust.
This account shall include amounts reserved by the utility for
losses through accident, fire, flood, or other hazards to its own
property or property leased from others, not covered by insurance.
The amounts charged to account 924, Property Insurance, or
other appropriate accounts to cover such risks shall be credited to
this account.
The account is used to record the interest on the balance in
account 228100. The Arkansas Public Service Commission gave
permission to EAI in Act 434, House Bill 1898 to calculate interest
on the balance in account 228100. "Simple interest on any
balance, credit, or debit in the storm cost reserve account shall
accrue at a rate equal to the electric public utility's last approved
rate-base rate of return."
To record 2009 ice storm O&M recovery costs allocated to
wholesale customers. Account is necessary to maintain the
balance of EAI 2009 Non-Retail Ice Storm costs for use in future
Wholesale Formula Rate filings.
This account includes proceeds from interim insurance claims and
CDBG (Community Development Block Grants) applications
which need to be separately captured until the final
allocation/determination of amounts is known.
This account will be used to move debit balances in accumulated
provision for property insurance subaccounts 228.1 to a regulatory
asset 182.3 subaccount to comply with FERC reporting.
E-9 Page 39 of 99
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41 Schedule E-9
Arkansas Public Service Commission
Chart of Accounts
Minimum Filing Requirements
Partially Projected Test Year Ended
Entergy Arkansas, Inc.
March 31, 2015
Docket No. 15-015-U
(1)
LN
(2)
Account
(3)
Account Title
412
228200
Accum Prov For Injuries & Dam
This account shall be credited with amounts charged to account
925, Injuries and Damages, or other appropriate accounts, to
meet the probable liability, not covered by insurance, for deaths or
injuries to employees and others and for damages to property
neither owned nor held under lease by the utility.
413
228210
Reserve For Inj & Dam - Legal
414
228301
Acc Prov-Pen&Ben-Hosp Res-Adj
415
228308
Acc Prov-P&B-Opeb
This account should represent probable liabilities, not covered by
insurance, for lawsuits over $75,000 for deaths or injuries to
employees and others.
This account is used to record the SFAS 112 and the amount of
active medical and dental claims incurred, but not yet reported on
the books.
This account represents the liability for other postretirement retiree
health and life benefits (OPEB) in accordance with SFAS 158/106.
416
228400
Acc Misc-Operating Prov
417
228401
Accum Prov - Coal Car Maint
418
228402
Ltd - Decomm & Decontam
419
228403
Acc Provision-Commer Litigatio
420
229000
Accum. Prov. For Rate Refund
421
230000
Asset Retirement Obligations
422
230007
Asset Retirement Obilig-Fos
423
230008
Asset Retirement Obilig -Hydro
424
230009
Asset Retirement Obligat-Other
425
(4)
Account Description
This account shall include all operating provisions which are not
provided for elsewhere.
This account represents the total coal car maintenance reserve
that is maintained to match expense over the life of the coal cars.
This account is used to record long-term decontamination and
decommissioning fees.
This account shall represent probable liabilities, not covered by
insurance, for lawsuits over $75,000 for commercial litigation.
This account shall be credited with amounts charged to Account
449.1, Provisions for Rate Refunds, to provide for estimated
refunds where the utility is collecting amounts in rates subject to
refund.
This account shall include the amount of liabilities for the
recognition of asset retirement obligations related to electric utility
plant and nonutility plant that gives rise to the obligations. This
account shall be credited for the amount of the liabilities for asset
retirement obligations with amounts charged to the appropriate
electric utility plant accounts or nonutility plant account to record
the related asset retirement costs.
This account contains the liability for asbestos removal costs for
fossil generating units, as determined under the provisions of
SFAS 143/FIN 47. The balance in this account will increase each
month by the monthly accretion of the liability for asbestos
removal costs at fossil generating units.
This account contains the liability for asbestos removal costs for
hydro generating units, as determined under the provisions of
SFAS 143/FIN 47. The balance in this account will increase each
month by the monthly accretion of the liability for asbestos
removal costs at hydro generating units.
This account contains the liability for asbestos removal costs for
other generating units, as determined under the provisions of
SFAS 143/FIN 47. The balance in this account will increase each
month by the monthly accretion of the liability for asbestos
removal costs at other generating units.
Current and Accrued Liabilities
426
231000
Notes Payable
427
232000
Accounts Payable
This account shall include the face value of all notes, drafts,
acceptances, or other similar evidences of indebtedness, payable
on demand or within a time not exceeding one year from date of
issue, to other than associated companies.
This account shall include all amounts payable by the utility within
one year, which are not provided for in other accounts.
E-9 Page 40 of 99
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41 Schedule E-9
Arkansas Public Service Commission
Chart of Accounts
Minimum Filing Requirements
Partially Projected Test Year Ended
Entergy Arkansas, Inc.
March 31, 2015
Docket No. 15-015-U
(1)
LN
(2)
Account
428
232002
Fuel Suppliers (Control)
429
232004
Incentive Comp
430
232006
Accrued Payroll
431
232008
Severance Liability
432
232009
Helping Hands-Empl. Contrib.
433
232010
Political Action Committee
434
232011
Empl. Charitable Contributions
435
232012
Credit Unions
436
232013
U.S. Savings Bonds
437
232015
Entergy Empl Savings Plan
438
232016
Payroll
439
232017
Payroll Administrative Fees
This account should include payroll deductions for employee
contributions to the following deduction codes which will be
cleared on AP1 journals via funding. 304 Manual Check
Replacement; RELO Relocation Net; CLUB Club membership
Net; GIFT Gift Card Net; FINC Financial Counseling Net; TRPN
Total Reward Deduct; PUCA Personal Use Corp Air Net.
440
232019
Garnishments
This account should include payroll deductions for employee
contributions to the following deduction codes which will be
cleared on AP1 journals via funding: 110-Child Support-26
Deducts; 111-Child Support; 24 Deductions; G15-Court Ordered.
(3)
Account Title
(4)
Account Description
This account records payables to fuel suppliers related to gas
purchases.
This account shall include the estimated employee incentive
compensation accrual.
This amount shall include the amount of salaries and wages
earned and accrued, but not yet paid.
This account contains the balance of severance package accruals
for the Vision Service Plan (VSP).
This account should include payroll deductions for employee
donations to Helping Hands.
This account should include payroll deductions for employee
contributions to the following deduction codes which will be
cleared on AP1 journals via funding: 310 Enpac - Arkansas.
This account should include payroll deductions for employee
charitable contributions which are cleared on AP1 journals via
funding.
This account should include payroll deductions for credit unions to
the following deduction codes: 352 UW - Grimes; 742 UW Pine
Belt Region; 785 Uw-West Central Mississippi; 354 UW
Beaumont; 680 UW-St Johns; 901 United Way of Fort Smith
Area; 356 UW - Orange; 952 Uw-Baton Rouge Capital Area; 575
UW - New Orleans; N901 United Way of Greater Oswego; 600
UW - Hammond
This account should include payroll deductions for employee
contributions to the following deduction codes which will be
cleared on AP1 journals via funding: 240-Riverland Credit
Union;255-Searcy Credit Union; N200-Teg Federal Credit Union;
241-Breco Credit Union; 260-El Dorado Fed. Credit Union; N201Oswego Co Public Employees Fcu; 242-Pilgrim Credit Union; 260Lion Federal Credit Union; N202-Flushing Savings Bank; 245Little Rock Credit Union; 265-Riverland Credit Union Loan; N203Waterside Qside Fed Credit Un; 250-Pine Bluff Credit Union; 285El Dorado Fed. Credit Un Loan; N204-Municipal Credit Union;
W242-Pilgrim Credit Union 52 Deduct.
This account should include payroll deduction for employee
contributions to ESOP.
This account should include payroll deductions for employee
contributions to the following deduction codes which will be
cleared on AP1 journals via funding: 100 Entergy 401(K) Savings
Plan Before Tax; 100 Entergy 401(K) Savings Plan After Tax;
051 Entergy 401(K) Catch up Savings Plan Before Tax.
E-9 Page 41 of 99
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41 Schedule E-9
Arkansas Public Service Commission
Chart of Accounts
Minimum Filing Requirements
Partially Projected Test Year Ended
Entergy Arkansas, Inc.
March 31, 2015
Docket No. 15-015-U
(1)
LN
(2)
Account
441
232021
Union Dues
This account should include payroll deductions for employee
contributions to the following deduction codes: 194-Union Dues
Ibew 300; 224-Union Pol Ed; N206-Ibew Savings Plan; 196-Union
Assessment - Ibew 300; I100-Union Dues - Uwua;W200-Pilgrim
Union Dues Unit 1 #369; 198-Union Dues Ibew "a" 300; N100Union Dues Ibew 97 Ba Member; W200-Pilgrim Union Dues Unit
1 #387; 203-Union Dues Uwua Pilgrim; N101-Union Dues Ibew 97
Agency; W201-Pilgrim Union Dues Unit 2 #369; 204-Pilgrim
Initiation Fee; N102-Union Dues Ibew 97 A Members; W202-Plgm
Initiation Fee Unit 1#369; 207-Local 369 Technical Union Dues;
N103-Cope Ibew 97; W202-Plgm Initiation Fee Unit 1#387; 209Local 590 Engineers Union Dues; N110-Union Dues Uwua 1&2;
W203-Pilgrim Initiation Unit 2 #369; 212-Union Dues Security
Pilgrim; N111-Union Dues Uwua 1&2 Agency; W206-Pilgrim Local
369 Pac; 223-Uwua Om&c Union Dues;N120-Union Dues
Teamsters 456; W207-Uwua Local 369 Cope.
442
232024
Energy Concern
443
232026
Esch. Deposits/Interest
444
232027
Entergy Emp Svgs Plan-Co Cont
445
232028
Helping Hands-Customers Contr
446
232029
Employee Reward Points
447
232030
HSA_Health Care_Dep Care
448
232032
Gen Acctg Month End Accrual
449
232033
Radwaste Accrual-Non-Rev
450
232034
A/P Unbilled Receipt - Mmis
This account should include payroll deductions for employee
contributions to the following deduction codes which will be
cleared on AP1 journals via funding: 294 Cust. Assist. Energy
Concern.
This account includes escheated customer deposits. Reconcile
the GL balance per PeopleSoft to the balance per CCS (FS10N)
report. Differences in this account are going to be payments
made to the state (CCS does not record payments) and any
escheated balances not yet paid to the state. The account is also
subject to timing differences between the escheat date and the
payment date.
This account should include payroll deductions for employee
contributions to the following deduction codes which will be
cleared on AP1 journals via funding: 100 Entergy 401(K) Savings
Plan Non-Taxable; 100 Entergy 401(K) Savings Plan PTax Ben;
146-Nmc Profit Sharing Annual 5%; 149-Nmc Profit Sharing
Annual; W105-401(k) Savings Plan.
The account should contain customer Helping Hands donations
billed through Customer Care System (CCS).
Employee rewards and recognition points liability. Reward points
accrued and payments to the vendor for the redemptions of the
points will be in this account.
This account should include payroll deductions for employee
contributions to the following deduction codes which will be
cleared on AP1 journals via funding: 048-Employee Health
Savings Bt.
This account should include general and month-end accruals that
meet policy.
This account is used to record various AP accruals for radwaste
related to various companies such as GE, EPOUS, and American
Wind Energies.
This account is fed directly from Indus Passport for receipt
transactions and directly from PeopleSoft AP for invoice
transactions. The account is credited when items are received and
debited when the matched invoices are sent to PeopleSoft AP
and posted to GL via an AP1 journal. Note that the AP payments
relieve liability based on latest purchase order (PO) price. Any PO
price revisions should generate a transaction that updates the
inventory value for the change in purchase price as well as adjust
the amount booked to the liability account. This account is also
used to accrue taxes and discounts lost/earned.
451
232036
Contract Incentives Payable
(3)
Account Title
(4)
Account Description
This account is used to capture dollars withheld from contractors
until the job has been completed. Items in this account are paid
when job is complete.
E-9 Page 42 of 99
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41 Schedule E-9
Arkansas Public Service Commission
Chart of Accounts
Minimum Filing Requirements
Partially Projected Test Year Ended
Entergy Arkansas, Inc.
March 31, 2015
Docket No. 15-015-U
(1)
LN
(2)
Account
(3)
Account Title
452
232040
Employee Supplemental Life In
453
232041
Entergy Employee Svgs Loans
454
232050
Other Witholding
455
232053
Dept. Of Energy-Nuclear Fuel
456
232055
River Fuel Trust
457
232058
A/P Oracle Outstanding Checks
458
232059
Cust Deposit Refnd-Chemical Bk
459
232063
Corp Procurment Cards-Citibank
460
232068
Payroll Deductions for Clubs
461
232072
A/P Accruals - CWIP
462
232073
ROW Escheatment
463
232074
MISO Payable
464
232075
Misc. A/R - Customer Refunds
465
232076
Residual Load Payable
466
232082
A/P - Co-Owner MISO Credits
467
232104
Fuel Coal Accruals
468
232214
Purchased Power Accruals
469
232708
A/P - Bulk Power
470
232710
A/P - Oracle
(4)
Account Description
This account should include payroll deductions for employee
contributions to the following deduction codes which will be
cleared on AP1 journals via funding: 082-Supplemental Life-J&H;
083-Supplemental Life-Amer Gen; 185-Provident Insurance Personal.
This account should include payroll deductions for employee
contributions to the following deduction codes which will be
cleared on AP1 journals via funding: 130 Savings Plan Loan
Repayment.
This account should include payroll deductions for employee
contributions to the following deduction codes which will be
cleared on AP1 journals via funding: N36-Domestic Partner (Dpc);
282-Welfare & Rec; VKT-After Tax Parking; 300-Miscellaneous
Onetime Ded.; VPA-Before Tax Parking; 076-Universal Life; I191The Traveler's Insurance; VPB-Before Tax Van Pool/public; 088Metpay; I192-Metropolitan Life; VPT-After Tax Pool/public; 097Deferral Comp W/Amt; I193-Equitable Insurance; W088-Metpay 52 Deducts'; 99-Deferral Comp W% + Match; 94-C. Barry Smith
Auto Home Ins;W300-Misc Deduction Weekly.
Monthly accrual on nuclear generation for the spent fuel disposal
fees payable to the Department of Energy. Payment is made on
the last day of the month following a quarter-end for the previous
quarter.
To record the payable to the Trust for the monthly burn charges
and daily lease charges. Payments are made on the last day of
the month following quarter-end.
This account is a re-class of account 234011 for outstanding
checks.
This account shall include outstanding check refunds due to
customers issued from Chase, which was acquired by Chemical
Bank.
This account is used to track the balance owed to Citibank per
use of the Corporate Purchasing Card.
This account should include employee deductions for Live Wires
(PR1), funding AP1 and clubs.
This account records the portion of the month-end payable
accruals in CWIP Account 107000.
The purpose of this account is to hold funds from uncashed Rightof-Way (ROW) checks that will be escheated to the appropriate
state.
When Entergy joins MISO, there will be weekly invoices sent to
each Operating Company from MISO with either a net charge or a
net credit.
This account includes refunds processed through Miscellaneous
Accounts Receivables.
Payable to external MISO market participants for LBA residual
load billing.
Payables to co-owners for their ownership share of MISO credits.
This account maintains outstanding payables related to coal
inventory purchases. Coal Invoices processed by Coal Supply are
charged to this account to offset the credits posted by the monthly
CLC journal based upon RCMS (Railcar & Coal Maintenance
System) reports.
This account is used to accrue monthly co-generation purchases.
This account should include accrued bulk power net expenses
due to various vendors.
This account is a monthly re-class of a portion of account 234011
in the AP6 re-class (Journal Mask AP6).
E-9 Page 43 of 99
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41 Schedule E-9
Arkansas Public Service Commission
Chart of Accounts
Minimum Filing Requirements
Partially Projected Test Year Ended
Entergy Arkansas, Inc.
March 31, 2015
Docket No. 15-015-U
(1)
LN
(2)
Account
471
232711
Accts Payable-Unclaimed Proper
This is a clearing account for AP checks escheated to the state.
472
232801
Uncashed Payroll Checks
473
232802
Stale Dated Payroll Checks
474
232850
MISO Transmission Payable
475
232914
Low-Level Radwaste Disposal
This account contains all current (< 60 days) checks and
adjustments to the payroll bank account.
This account contains all stale dated (> 60 days) checks and
adjustments to the payroll bank account.
This account shall represent the amounts Entergy needs to pay
MISO to settle transmission service schedules.
This account contains amount reserved for disposal of low-level
rad waste stored at the Palisades plant at the time of Entergy's
acquisition of the plant. This amount will be cleared when the site
contracts with a 3rd party for removal and disposal.
476
477
232998
232APD
Source Systems-Deflt Liability
Invoice trueup-CLEAResult
478
232BEN
Accrued Employee Benefits
479
232DCR
Defined Contrib Restoration Pl
480
232FUA
Fuel Account Purchase Accruals
481
232JTO
Payable to Joint Trans Owners
482
232PAS
A/P Unbilled Receipts-Passport
483
232SAI
A/P - Saic
This account will contain all unpaid, but accrued, SAIC invoices.
484
232STO
Accrued Stock Options
485
232U03
Fuel Oil Cost Accruals
486
232VAC
Accrued Vacation Liability
487
232WHL
Backup Withholding
This account will capture the accrued stock option liability, as well
as any adjustments related to the accrual.
This account records payables to fuel suppliers associated with
fuel oil purchases.
This account represents Entergy Arkansas, Inc.'s (EAI) vacation
liability as of the current month. The calculation of the liability is
an automated process done by the payroll dept., which multiplies
the available vacation hours remaining for the year times the
employees' hourly rates.
This account is used to withhold dollars from vendors who have
been identifed by the IRS as Backup Withholding Vendors. A
certain % of the invoice amount is withheld and paid to the IRS
according to the guidelines outlined by the IRS.
488
232X09
Payables-CF Reclass
(3)
Account Title
(4)
Account Description
Used to record balancing records to unbalanced journals.
This account will be used as the offset liability account associated
with recording, in journal mask APD, the expenses related to
incentive checks issued by CLEAResult for various energy
efficient programs.
This account should include the estimated benefits liability as of
the current month. The account is trued up annually to reflect
actual benefits costs incurred.
This account balance shall contain both contributions to the
Defined Contribution Restoration Plan and various market
fluctuations.
Account will be used for Fuel Accounting purchase accruals only.
This account will accrue nuclear fuel and NOX (Nitrogen Oxide)
allowance purchases.
This account captures the amounts payable to third party joint
transmission owners that are passed to Entergy via MISO.
Entergy will neeed to pay third party based on the joint owner
agreements.
This account is fed directly from Passport for receipt transactions
and directly from PeopleSoft AP for invoice transactions. The
account is credited when items are received and debited when the
matched invoices are sent to PeopleSoft AP and posted to GL via
AP1 journal. This account is also used to accrue taxes and
discounts lost/earned.
Accounts ending in "X06", "X07, "X08", and "X09" were created for
the sole purpose of being able to journalize certain cash flow
statement reclassifications into the general ledger. These
accounts do not contain any original operational transactions.
They are simply used to modify cash flow statement line item
presentations in Entergy's internally generated cash flow
statements.
E-9 Page 44 of 99
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41 Schedule E-9
Arkansas Public Service Commission
Chart of Accounts
Minimum Filing Requirements
Partially Projected Test Year Ended
Entergy Arkansas, Inc.
March 31, 2015
Docket No. 15-015-U
(1)
LN
(2)
Account
489
233000
Notes Payable Associated Co
Notes Payable on inter-company loans are booked when lender's
distributed notes to affiliate companies and when repayments is
made on the Note. These accounts are not related to the interest
accrual and interest payments on the loan.
490
234000
A/P - Affiliate
This account includes amounts owing to associated companies on
notes, drafts, acceptances, or other similar evidences of
indebtedness, and open accounts payable on demand or not
more than one year from date of issue or creation.
491
234001
Money Pool Borrowing
The Money Pool is an internal cash management tool and
financing vehicle in which all operating companies participate,
some as borrowers and some as lenders, and as a result, bear
the benefit or cost through interest income or expense. This
account shall include amounts borrowed from the Money Pool.
492
234010
Inter-Unit Payable - GL/Misc
493
234011
Inter-Unit Payable - AP/TR
494
234017
A/P - Restricted Stock
495
234018
MISO Intercompany Payable
496
497
234019
234711
Residual Load InterCo Payable
AP Bulk Power/System Agreement
498
234811
A/P - Affiliate (Fuel)
499
234842
AP - AFFILIATE -Misc Rec
This account is related to the intercompany interest
expense/payable between associated companies.
PeopleSoft AP/TR offset account for all Business Units processing
invoices in PeopleSoft AP through the One Check/One Wire
process. This account is cleared through the AP6 allocation
process at the end of the month and set to reverse at the
beginning of the next month. Funding journals to relieve this
account occurs through PeopleSoft TR.
This account records subsidiaries' affiliate payable to Entergy
parent company related to the Restricted Stock program.
Settlement will occur annually at vesting date.
Payable between operating companies to settle cash for MISO
charges that were paid on the weekly invoices but allocated
differently in the ISB.
Payable to other Entergy OpCos for LBA residual load billing.
This account will be used to record bulk power and system
agreement intercompany payable to operating companies.
The balance in these account reflects the System Fuels, Inc.
invoices that are billed to the Operating Companies (OpCo's)
monthly. This account is reconciled by the Fuels Department.
This intercompany payable account represents the Point-to-Point
(PTP) and Network Integration Transmission Services (NITS)
transmission service revenue. The account set up to separate
these PTP and NITS transactions, which were booked to Account
234811, because the reconciliation of this account will be
performed by Miscellaneous Receivables Department.
500
234911
A/P - N.F. Trust Affiliate
This account will be used by the Operating Companies to record
the affiliate payable transactions related to the lease payments to
the River Fuel Trust companies (now required to be consolidated).
501
234FFR
AP AFFILATE Financial Rights
502
235001
Customer Deposits (Active)
503
235006
Customer Deposits-Receivable
Intercompany payable account for financial rights compensation.
This new account is needed to account for and track financial
rights due to Entergy Op Co. (s) funding supplemental upgrades
to transmission structures.
This account shall include all amounts deposited with the utility by
customers as security for the payment of bills.
This account represents customer deposits for reimbursable
projects. The deposits are either refunded to the customer at the
completion of the project or applied t the final invoice of the
project.
(3)
Account Title
(4)
Account Description
E-9 Page 45 of 99
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41 Schedule E-9
Arkansas Public Service Commission
Chart of Accounts
Minimum Filing Requirements
Partially Projected Test Year Ended
Entergy Arkansas, Inc.
March 31, 2015
Docket No. 15-015-U
(1)
LN
(2)
Account
504
236000
Taxes Accrued
This account shall be credited with the amount of taxes accrued
during the accounting period, corresponding debits being made to
the appropriate accounts for tax charges. Such credits may be
based upon estimates, but from time to time during the year as
the facts become known, the amount of the periodic credits shall
be adjusted so as to include as nearly as can be determined in
each year the taxes applicable thereto.
505
236105
Non Income Tax Contingency
This account shall be credited with the amount of taxes accrued
during the accounting period, corresponding debits being made to
the appropriate accounts for tax charges. Such credits may be
based upon estimates, but from time to time during the year as
the facts become known, the amount of the periodic credits shall
be adjusted so as to nearly as can be determined in each year the
taxes applicable thereto. This account represents the reserve of
taxes other than income taxes.
506
236111
Federal Income Tax
This account shall be credited with the amount of taxes accrued
during the accounting period, corresponding debits being made to
the appropriate accounts for tax charges. Such credits may be
based upon estimates, but from time to time during the year as
the facts become known, the amount of the periodic credits shall
be adjusted so as to include as nearly as can be determined in
each year the taxes applicable thereto. This subaccount contains
the balance of the federal income taxes payable.
507
236112
State Income Tax
This account shall be credited with the amount of taxes accrued
during the accounting period, corresponding debits being made to
the appropriate accounts for tax charges. Such credits may be
based upon estimates, but from time to time during the year as
the facts become known, the amount of the periodic credits shall
be adjusted so as to include as nearly as can be determined in
each year the taxes applicable thereto. This subaccount contains
the balance of the state income taxes payable.
508
236113
Unemployment - Federal
509
236114
Unemployment - State
510
236115
Fica
511
236122
Excise Tax - State
This account represents the Federal Unemployment
Compensations Tax (FUTA) accrued on a fixed rate and payable
to the IRS quarterly.
This account represents the State Unemployment Compensations
Tax (SUTA) accrued on a fixed rate and payable to the state
quarterly.
This account represents the Company Contribution (Co-match) to
employees social security and medicare program.
This account shall be credited with the amount of taxes accrued
during the accounting period, corresponding debits being made to
the appropriate accounts for tax charges. Such credits may be
based upon estimates, but from time to time during the year as
the facts become known, the amount of the periodic credits shall
be adjusted so as to include as nearly as can be determined in
each year the taxes applicable thereto. This subaccount contains
the balance to the State Excise Taxes Payable for various state
excise taxes.
512
236123
Excise Tax - Federal
(3)
Account Title
(4)
Account Description
This account shall be credited with the amount of taxes accrued
during the accounting period, corresponding debits being made to
the appropriate accounts for tax charges. Such credits may be
based upon estimates, but from time to time during the year as
the facts become known, the amount of the periodic credits shall
be adjusted so as to include as nearly as can be determined in
each year the taxes applicable thereto. This subaccount contains
the balance to the Federal Excise Taxes Payable for federal
excise taxes.
E-9 Page 46 of 99
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41 Schedule E-9
Arkansas Public Service Commission
Chart of Accounts
Minimum Filing Requirements
Partially Projected Test Year Ended
Entergy Arkansas, Inc.
March 31, 2015
Docket No. 15-015-U
(1)
LN
(2)
Account
513
236142
Ad Valorem
This account shall be credited with the amount of taxes accrued
during the accounting period, corresponding debits being made to
the appropriate accounts for tax charges. Such credits may be
based upon estimates, but from time to time during the year as
the facts become known, the amount of the periodic credits shall
be adjusted so as to include as nearly as can be determined in
each year the taxes applicable thereto. This subaccount contains
the balance to the Ad Valorem Taxes Payable for Louisiana ad
valorem taxes for the EAI's Ouachita Power Plant located in
Louisiana.
514
236143
Ad Valorem Missouri
This account shall be credited with the amount of taxes accrued
during the accounting period, corresponding debits being made to
the appropriate accounts for tax charges. Such credits may be
based upon estimates, but from time to time during the year as
the facts become known, the amount of the periodic credits shall
be adjusted so as to include as nearly as can be determined in
each year the taxes applicable thereto. This subaccount contains
the balance to the Ad Valorem Taxes Payable for Missouri ad
valorem taxes.
515
236147
Ad Valorem - Ar
This account shall be credited with the amount of taxes accrued
during the accounting period, corresponding debits being made to
the appropriate accounts for tax charges. Such credits may be
based upon estimates, but from time to time during the year as
the facts become known, the amount of the periodic credits shall
be adjusted so as to include as nearly as can be determined in
each year the taxes applicable thereto. This subaccount contains
the balance to the Ad Valorem Taxes Payable for Arkansas ad
valorem taxes.
516
236152
Franchise Tax - State
517
236153
Franchise Tax-Local
This account shall be credited with the amount of taxes accrued
during the accounting period, corresponding debits being made to
the appropriate accounts for tax charges. Such credits may be
based upon estimates, but from time to time during the year as
the facts become known, the amount of the periodic credits shall
be adjusted so as to include as nearly as can be determined in
each year the taxes applicable thereto. This subaccount contains
the balance for corporate franchise taxes for the State of
Arkansas.
This account shall be credited with the amount of taxes accrued
during the accounting period, corresponding debits being made to
the appropriate accounts for tax charges. Such credits may be
based upon estimates, but from time to time during the year as
the facts becomeknown, the amount of the periodic credits shall
be adjusted so as to include as nearly as can be determined in
each year the taxes applicable thereto. This subaccount contains
the balance to the local franchise taxes for Arkansas.
518
236157
Franchise Tax - Missouri
(3)
Account Title
(4)
Account Description
This account shall be credited with the amount of taxes accrued
during the accounting period, corresponding debits being made to
the appropriate accounts for tax charges. Such credits may be
based upon estimates, but from time to time during the year as
the facts become known, the amount of the periodic credits shall
be adjusted so as to include as nearly as can be determined in
each year the taxes applicable thereto. This subaccount contains
the balance for corporate franchise taxes for the State of Missouri.
E-9 Page 47 of 99
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41 Schedule E-9
Arkansas Public Service Commission
Chart of Accounts
Minimum Filing Requirements
Partially Projected Test Year Ended
Entergy Arkansas, Inc.
March 31, 2015
Docket No. 15-015-U
(1)
LN
(2)
Account
519
236161
State Sales & Use Tax
This account shall be credited with the amount of taxes accrued
during the accounting period, corresponding debits being made to
the appropriate accounts for tax charges. This subaccount
contains the balance for the monthly use tax accruals net of
monthly payments for the State of Arkansas use tax accrual on
fuel purchases at the Arkansas fossil plants.
520
236172
Regulatory Comm Fees
This account shall be credited with the amount of taxes accrued
during the accounting period, corresponding debits being made to
the appropriate accounts for tax charges. Such credits may be
based upon estimates, but from time to time during the year as
the facts become known, the amount of the periodic credits shall
be adjusted so as to include as nearly as can be determined in
each year the taxes applicable thereto. This subaccount contains
the balance to regulatory commission fees.
521
236180
Railcar Tax - Missouri
This account shall be credited with the amount of taxes accrued
during the accounting period, corresponding debits being made to
the appropriate accounts for tax charges. Such credits may be
based upon estimates, but from time to time during the year as
the facts become known, the amount of the periodic credits shall
be adjusted so as to include as nearly as can be determined in
each year the taxes applicable thereto. This subaccount contains
the balance to the railcar taxes payable to Missouri.
522
236181
Railcar Tax - Wyoming
This account shall be credited with the amount of taxes accrued
during the accounting period, corresponding debits being made to
the appropriate accounts for tax charges. Such credits may be
based upon estimates, but from time to time during the year as
the facts become known, the amount of the periodic credits shall
be adjusted so as to include as nearly as can be determined in
each year the taxes applicable thereto. This subaccount contains
the balance to the railcar taxes payable to Wyoming.
523
236182
Railcar Tax - Other States
This account shall be credited with the amount of taxes accrued
during the accounting period, corresponding debits being made to
the appropriate accounts for tax charges. Such credits may be
based upon estimates, but from time to time during the year as
the facts become known, the amount of the periodic credits shall
be adjusted so as to include as nearly as can be determined in
each year the taxes applicable thereto. This subaccount contains
the balance to the railcar taxes payable to various other states.
524
236183
Railcar Tax - Arkansas
This account shall be credited with the amount of taxes accrued
during the accounting period, corresponding debits being made to
the appropriate accounts for tax charges. Such credits may be
based upon estimates, but from time to time during the year as
the facts become known, the amount of the periodic credits shall
be adjusted so as to include as nearly as can be determined in
each year the taxes applicable thereto. This subaccount contains
the balance to the railcar taxes payable to Arkansas.
525
236185
Railcar Tax - Colorado
This account shall be credited with the amount of taxes accrued
during the accounting period, corresponding debits being made to
the appropriate accounts for tax charges. Such credits may be
based upon estimates, but from time to time during the year as
the facts become known, the amount of the periodic credits shall
be adjusted so as to include as nearly as can be determined in
each year the taxes applicable thereto. This subaccount contains
the balance to the railcar taxes payable to Colorado.
(3)
Account Title
(4)
Account Description
E-9 Page 48 of 99
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41 Schedule E-9
Arkansas Public Service Commission
Chart of Accounts
Minimum Filing Requirements
Partially Projected Test Year Ended
Entergy Arkansas, Inc.
March 31, 2015
Docket No. 15-015-U
(1)
LN
(2)
Account
526
236200
Use Tax Accrual
527
236211
Arkansas Use Tax Accrual
528
236240
Gross Receipts & Sales Tax
This account shall be credited with the amount of taxes accrued
during the accounting period, corresponding debits being made to
the appropriate accounts for tax charges. This subaccount
contains the balance for the monthly gross receipts and sales tax
accruals net of monthly payments for the 6% Arkansas sales tax
for company use of power from the generating plants.
529
236255
1% Jefferson County
This account shall be credited with the amount of taxes accrued
during the accounting period, corresponding debits being made to
the appropriate accounts for tax charges. This subaccount
contains the balance for the monthly use tax accruals net of
monthly payments for the Jefferson County, Arkansas use tax
accrual on fuel purchases at the White Bluff Plant.
530
236260
Sales Use Tax-Union County AR
531
236269
Pulaski County
Used for use tax accruals on fuel delivered to Union County,
Arkansas.
This account shall be credited with the amount of taxes accrued
during the accounting period, corresponding debits being made to
the appropriate accounts for tax charges. This subaccount
contains the balance for the monthly use tax accruals net of
monthly payments for the Pulaski County, Arkansas use tax
accrual for fuel purchases at the Lynch Plant.
532
236271
1% Independence County
This account shall be credited with the amount of taxes accrued
during the accounting period, corresponding debits being made to
the appropriate accounts for tax charges. This subaccount
contains the balance for the monthly use tax accruals net of
monthly payments for the Indepence County, Arkansas use tax
accrual on fuel purchases at the Independence Plant.
533
236285
1% Lafayette County
This account shall be credited with the amount of taxes accrued
during the accounting period, corresponding debits being made to
the appropriate accounts for tax charges. This subaccount
contains the balance for the monthly use tax accruals net of
monthly payments for the Lafayette County, Arkansas use tax
accrual on fuel purchases at the Couch Plant.
534
236296
1% Hot Springs County
535
236515
Cash Deposits with IRS
This account shall be credited with the amount of taxes accrued
during the accounting period, corresponding debits being made to
the appropriate accounts for tax charges. This subaccount
contains the balance for the monthly use tax accruals net of
monthly payments for the Hot Spring County, Arkansas use tax
accrual on fuel purchases at the Lake Catherine Plant and the
Remmel Hydro Plant.
This account is used to facilitate the tracking of cash deposits
made with the IRS.
(3)
Account Title
(4)
Account Description
This account shall be credited with the amount of taxes accrued
during the accounting period, corresponding debits being made to
the appropriate accounts for tax charges. This subaccount
contains the balance for the monthly use tax accruals net of
monthly payments for purchases of materials and taxable services
in the State of Arkansas.
This account shall be credited with the amount of taxes accrued
during the accounting period, corresponding debits being made to
the appropriate accounts for tax charges. This subaccount
contains the balance for the monthly use tax accruals net of
monthly payments for the State of Arkansas use tax accrual on
nuclear fuel purchases at the Arkansas Nuclear One Plant.
E-9 Page 49 of 99
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41 Schedule E-9
Arkansas Public Service Commission
Chart of Accounts
Minimum Filing Requirements
Partially Projected Test Year Ended
Entergy Arkansas, Inc.
March 31, 2015
Docket No. 15-015-U
(1)
LN
(2)
Account
536
236C48
FIN 48 Current
The portion of the unrecognized tax benefit classified as a current
liability based on anticipated payment (or receipt) of cash within
one year. The amounts within 12 months are analyzed quarterly.
537
236F48
FIN48
538
236FCO
FIN48 Fed Current Def Offset
Current tax account used to reclassify non-current taxes accrued
on uncertain tax positions. This account is used as an offset
when a deferred tax asset/deferred tax liability was originally
booked in relation to the underlying tax adjustment.
This account is used to book ASC 740-10 items that differ from
the amount taken, or expected to be taken, in a tax return for the
current year. The amount of a net operating loss carryforward is
reduced for an unrecognized tax benefit because it represents the
company’s potential future obligation to the taxing authority for a
tax position that was not recognized pursuant to ASC 740-10.
Separate accounts were created to distinguish b/t Fed and State
as well as Current vs. Noncurrent ADIT. (These accounts replace
190F49 used previously). This account is for the federal current
accumulated deferred income tax.
539
236FNO
FIN48 Fed NonCurrent Def Offst
This account is used to book ASC 740-10 items that differ from
the amount taken, or expected to be taken, in a tax return for the
current year. The amount of a net operating loss carryforward is
reduced for an unrecognized tax benefit because it represents the
company’s potential future obligation to the taxing authority for a
tax position that was not recognized pursuant to ASC 740-10.
Separate accounts were created to distinguish b/t Fed and State
as well as Current vs. Noncurrent ADIT. (These accounts replace
190F49 used previously). This account is for the federal noncurrent accumulated deferred income tax.
540
236N48
FIN 48 Noncurrent
541
236PRT
Accrued Payroll Taxes (All)
542
236SCO
FIN48 State Current Def Offset
This account contains those amounts not going to be settled
within the next twelve months. The timing of the settlement is
reevaluated quarterly.
This account includes the estimated payroll tax liability as of the
current month. The account is trued-up annually to reflect actual
taxes paid.
This account is used to book ASC 740-10 items that differ from
the amount taken, or expected to be taken, in a tax return for the
current year. The amount of a net operating loss carryforward is
reduced for an unrecognized tax benefit because it represents the
company’s potential future obligation to the taxing authority for a
tax position that was not recognized pursuant to ASC 740-10.
Separate accounts were created to distinguish b/t Fed and State
as well as Current vs. Noncurrent ADIT. (These accounts replace
190F49 used previously). This account is for the state current
accumulated deferred income tax.
543
237000
Interest Accrued
544
237002
Int On Customer Deposits
545
237006
Interest On Bank Loans
546
237191
Tax Liability
547
238000
Dividends Declared
(3)
Account Title
(4)
Account Description
This account shall include the amount of interest accrued but not
matured on all liabilities of the utility not including, however,
interest which is added to the principal of the debt on which
incurred.
This account represents the amount of interest payable on
customer deposits held.
This account represents the interest owed on various bank lines of
credit.
This account represents the interest reserved on FIN48 issues.
This account shall include the amount of dividends which have
been declared but not paid. Dividends shall be credited to this
account when they become a liability.
E-9 Page 50 of 99
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41 Schedule E-9
Arkansas Public Service Commission
Chart of Accounts
Minimum Filing Requirements
Partially Projected Test Year Ended
Entergy Arkansas, Inc.
March 31, 2015
Docket No. 15-015-U
(1)
LN
(2)
Account
548
238001
Dividends Declared Common
549
238002
Dividends Declared Pref.
550
241000
Tax Collections Payable
551
241001
Federal Income Tax Withheld
552
241002
F.I.C.A. Tax Withheld
553
241003
State Income Tax Withheld
554
241005
State Sales Tax Coll. - Oper.
555
241033
City Sales Taxes
556
241037
County Sales Tax
557
241115
Franchise Tax-Arkansas-Cis
558
241118
Alt Fuel & Weatherization Fees
559
241OVR
Tax Withholdings NY Overpays
560
242000
Misc Curr & Accrued Liab
561
242010
Undistributed Refunds
This account represents the amount of common stock dividends
payable to shareholders.
This account includes the amount of preferred stock dividends
which have been declared but not paid. Dividends are credited to
this account when they become a liability.
This account shall include the amount of taxes collected by the
utility through payroll deductions or otherwise pending transmittal
of such taxes to the proper taxing authority.
This account is used to record employees’ Federal Income Tax
withholding from paycheck until funded.
This account is used to record employees’ portion of Social
Security Tax withholding from paycheck until funded.
This account is used to record employees’ State Income Tax
withholding from paycheck until funded.
This account shall include the amount of state sales taxes
collected by the utility on its sales of electricity to be remitted to
the proper taxing authority.
This account shall include the amount of city sales taxes collected
by the utility on its sales of electricity to be remitted to the proper
taxing authority.
This account shall include the amount of county sales taxes
collected by the utility on its sales of electricity to be remitted to
the proper taxing authority.
This account is used to record the franchise tax liability owed by
the utility.
To account for Alternate Fuel and Weatherization fees collected
from customers per Act 120 2003
This account represents the tax liability for employee
overpayments in New York.
This account shall include the amount of all other current and
accrued liabilities not provided for elsewhere appropriately
designated and supported so as to show the nature of each
liability.
This account is used to record refunds to be given to customers.
562
242080
Audit Fees
This account is used to record the liability to pay outside auditors.
563
242100
LOC Fees
564
242111
MISO Letter of Credit Fees
565
242200
Deferred Revenue - MISO FTRs
566
242300
Misc Cur Liab-Decom & Decontam
This account should be used to track the accrued liability of fees
associated with LOCs and will clear when the payment is
processed.
This account should be used to track the accrued liability of fees
associated with the MISO Letter of Credit and will clear when the
payment is processed.
This account shall capture the deferred revenue associated with
MISO Financial Transmission Rights (FTRs). Melissa LeJeune
Reconciler: Jessica
This account is the long-term debt that captures the estimated
costs payable to the Department of Energy (DOE) of
decommissioning and decontamination (special assessment).
567
242309
Non-Qualified Pension SFAS 158
568
242401
Counterparty Deposit Liability
569
242410
Current Liability for Escrow
570
242500
Deferred Revenue - Mar
(3)
Account Title
(4)
Account Description
This account is used to record the current portion of the NonQualified Pension SFAS 158 liability.
This account is used to record the counterparty deposit received
in connection with margin cells on behalf of Entergy Nuclear
Power Marketing.
This account is used to record the current portion of the liabilty
related to the escrowed amount for the acquisition of Hinds and
Hot Spring plants.
This account is used to record the Miscellaneous Accounts
Receivable Contracts balance of unearned revenue for services
not yet provided.
E-9 Page 51 of 99
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41 Schedule E-9
Arkansas Public Service Commission
Chart of Accounts
Minimum Filing Requirements
Partially Projected Test Year Ended
Entergy Arkansas, Inc.
March 31, 2015
Docket No. 15-015-U
(1)
LN
(2)
Account
571
242CAW
AP Cushman & Wakefield
572
243000
Obligations Under Cap Lease
573
243103
Misc Capital Lease-Current
574
243205
River Fuel
575
(3)
Account Title
(4)
Account Description
This account is used as a clearing account for Cushman &
Wakefield charges.
This account shall include the portion, due within one year, of the
obligations recorded for the amounts applicable to leased property
recorded as assets in account 101.1, Property under Capital
Leases, account 120.6, Nuclear Fuel under Capital Leases (Major
only), or account 121, Nonutility Property.
This account is used to record the present value of Entergy
Arkansas capital leases under FERC.
Accounts 120600, 227000 and 243205 accounts are used to
capture the nuclear fuel under lease. The balance in this account
is offset by the sum of the current and non-current payable to
River Fuel Trust.
Deferred Credits
576
252000
Cust. Advances For Constr.
This account shall include advances by customers for construction
which are to be refunded either wholly or in part. When a
customer is refunded the entire amount to which he is entitled,
according to the agreement or rule under which the advance was
made, the balance, if any, remaining in this account shall be
credited to the respective plant account.
This account will be used as a prepaid CIAC to account for a
Facility Study Agreement between El Dorado Chemical Company
and Entergy Arkansas, Inc. for providing modifications to the EAI
transmission system to allow an EDC generation interconnection.
This project will be completed for Entergy Arkansas, Inc.
577
252A06
El Dorado Chemical/Non IPP
578
252A07
Little Rock Muni Airport/NonIP
This account will be used as a prepaid CIAC to account for
installing or upgrading equipment to provide dead-line closing
scheme at the EAI Distribution Facilities for Entergy Arkansas, Inc.
579
252A19
Peco Foods, Inc./Non IPP
This account will be used as a prepaid CIAC to account for Peco
Foods, Inc.'s billing for the transmission line modification as
described in the completed reimbursement agreement. The
project will be completed for Entergy Arkansas, Inc.
580
252A23
AR Elec. Cooperative Corp/Non IPP
This account will be used as a prepaid CIAC to account for AR
Electric Cooperative Corporation's billing for Entergy Arkansas,
Inc. to add a 161 kV breaker at the AECC Pocahontas Substation.
The project will be completed for Entergy Arkansas, Inc.
581
252A24
Conway Corporation/Non IPP
This account will be used as a prepaid CIAC to account for
Conway Corporation Middle Road Substation's billing for Entergy
Arkansas, Inc. for Engineering, Procurement, and Construction.
The project will be completed for Entergy Arkansas, Inc.
582
252B06
El Dorado Chemical/Non IPP TGU
583
252B07
Litle Rock Muni Airp/NonIPPTGU
584
253000
Other Deferred Credits
This account will be used for the Tax Gross Up (TGU) associated
with the Facility Study Agreement between El Dorado Chemical
Company and Entergy Arkansas, Inc. for providing modification to
the EAI transmission system to allow EDG generation
interconnection. This project will be completed for Entergy
Arkansas, Inc.
This account will be used for the Tax Gross UP (TGU) associated
with the installing or upgrading equipment to provide dead-line
closing scheme at the EAI Distribution Facilities for Entergy
Arkansas, Inc.
This account shall include advance billings and receipts and other
deferred credit items, not provided for elsewhere, including
amounts which cannot be entirely cleared or disposed of until
additional information has been received.
E-9 Page 52 of 99
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41 Schedule E-9
Arkansas Public Service Commission
Chart of Accounts
Minimum Filing Requirements
Partially Projected Test Year Ended
Entergy Arkansas, Inc.
March 31, 2015
Docket No. 15-015-U
(1)
LN
(2)
Account
585
253004
Accum Def Itc Other
586
25300N
Reserve for Impaired Asset
587
253012
Unfunded Pension Expense
588
253013
Supplemental Pension Plan
589
253014
Oth Def Credits - Fuel
590
253021
Med Cost Pay-Active ERRP Rcpt
591
253023
Defer Incen Comp Amt
This account records the liability for executive incentive
compensation upon which payment was elected to be deferred.
592
253040
Oth Def Credits-Source Systems
593
253044
LTIP - 2007-2009 Plan.
594
253045
LTIP - 2008-2010 Plan
595
253046
LTIP - 2009-2011 Plan
596
253047
LTIP - 2010-2012 Plan
Other deferred credits (253) as defined by the USOA, this subaccount was set upt to track deferred activity related to Source
Systems.
This account records the estimated liability for the 2007-2009
Long-Term Incentive Plan (LTIP). The LTIP liability is a
performance based plan measured using awarded ETR share
units times current market value plus dividends.
This account records the estimated liability for the 2008-2010
Long-Term Incentive Plan (LTIP). The LTIP liability is a
performance based plan measured using awarded ETR share
units times current market value plus dividends.
This account records the estimated liability for the 2009-2011
Long-Term Incentive Plan (LTIP). The LTIP liability is a
performance based plan measured using awarded ETR share
units times current market value plus dividends.
This account records the estimated liability for the 2010-2012
Long-Term Incentive Plan (LTIP). The LTIP liability is a
performance based plan measured using awarded ETR share
units times current market value plus dividends.
(3)
Account Title
(4)
Account Description
This account is used to record Accumulated Deferred Income Tax
Credits.
This account shall include a reserve for uncollectible payroll
advances against balances due from retired, deceased, and
terminated employees in account 13500N.
SFAS 158 Pension Liability - The year-end balance in this
account represents the funded status of the Company’s qualified
pension plans’ retirement liability. Funded status is the difference
between the projected benefit obligation and the fair market value
of assets in the external pension master trust. During the year,
SFAS 87 pension costs and funding to the external master trust
are recorded in this account. At year-end, the balance in this
account is adjusted to the actuarially determined SFAS 158
liability balance.
SFAS 158 Supplemental Pension Plan Liability - The year-end
balance in this account represents the funded status of the
Company’s non-qualified pension plans’ retirement liability.
Funded status is the difference between the projected benefit
obligation and the fair market value of assets in the external
pension master trust. During the year, SFAS 87 pension costs
and payments to participants are recorded in this account. At yearend, the balance in this account is adjusted to the actuarially
determined SFAS 158 liability balance.
This account is used to record the estimated provision for the
Arkansas Electric Cooperative Corporation (AECC) Substitute
Energy Dispute.
The obligation in this account represents amounts received under
the Federal Early Retiree Reinsurance Program (ERRP) that must
be used to lower increase in medical costs of active employees.
The Early Retiree Reinsurance Program was created as part of
the new health care reform legislation. Entergy will receive
reimbursement for certain medical claims for early retirees. Then
a portion of the cash received must be used to reduce future
increases in medical costs. This account will be used to keep
track of the portion of cash received under ERRP that will be used
to lower future active employee medical costs.
E-9 Page 53 of 99
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41 Schedule E-9
Arkansas Public Service Commission
Chart of Accounts
Minimum Filing Requirements
Partially Projected Test Year Ended
Entergy Arkansas, Inc.
March 31, 2015
Docket No. 15-015-U
(1)
LN
(2)
Account
597
253048
LTIP - 2011-2013 Plan
598
253101
Oth Def - EAI Plant In Service
599
253106
Oth Def-EAI Un-Unitized Plant
600
253107
Oth Def - EAI CWIP
601
253108
Oth Def - EAI Accumulated Depr
602
253111
Oth Def-EAI Accum Amort
603
253115
Book Gain On Sale Of Property
604
253118
Book-Gain On Sale Of Buildings
605
253190
Employment Litigation Liab
606
2531OU
Oth Def - Ouachita Gas Yd
607
253270
L.T. Pay. - (2012-2014 LTIP)
608
253271
L.T. Pay. - (2012-2014 LTIP)
609
253272
L.T. Pay. - (2013 - 2015 LTIP)
610
253400
Deferred Credit - Escrow
(3)
Account Title
(4)
Account Description
This account records the estimated liability for the 2011-2013
Long-Term Incentive Plan (LTIP). The LTIP liability is a
performance based plan measured using awarded ETR share
units times current market value plus dividends.
Per APSC Docket 09-84-U order, certain Incentive Costs were
disallowed along with the associated AFUDC and Capital
Suspense. This account will track the unitized closings from
account 253106. For reporting EAI retail rate filings, this account
should be netted with account 1010AM.
Per APSC Docket 09-84-U order, certain Incentive Costs were
disallowed along with the associated AFUDC and Capital
Suspense. This special account will track the un-unitized closings
from account 253107. For reporting EAI retail rate filings, this
account should be netted with account 106000.
Per APSC Docket 09-84-U order, certain Incentive Costs were
disallowed and reclassed from the normal capital account
(107000) to this special other deffered expense account for
reporting purposes. For reporting EAI retail rate filings, this
account should be netted with account 107000.
Per APSC Docket 09-84-U order, certain Incentive Costs were
disallowed along with the associated AFUDC and Capital
Suspense. This special account will track the Accumulated
Depreciation associated with the assets recorded to accounts
253106 and 253101. For reporting EAI retail rate filings, this
account should be netted with account 1080AM.
Per APSC Docket 09-84-U order, certain Incentive Costs were
disallowed along with the associated AFUDC and Capital
Suspense this special account will track the Accumulated
Amortization associated with the assets recorded to accounts
253106 and 253101. For reporting EAI retail rate filings this
account should be netted with account 1110AM. Only the
Accounting Department should charge this other defferred credit
account.
This account is used to record amortization of realized gain on
sale of leased buildings.
This account consists of amortization of the gain on the
sale/leaseback of AP&L buildings. The amortization will end in
May 2016.
To capture reserves and claims for legal as they pertain to
employment litigation claims, including EEOC, ADA, FLSA and
general litigation. To capture employment legal litigation liabilities
separate from injuries and damages payable.
This account is to capture the portion of gas payments made that
are attributable to the Ouachita Gas Yard.
This account is used to record subsidiaries' affiliate payable to
ETR related to the 2012-2014 Long-Term Incentive Plan which
became equity based beginning with the 2012-2014 plan.
This account records the estimated liability for the 2012-2014
Long-Term Incentive Plan (LTIP). The LTIP liability is a
performance based plan measured using awarded ETR share
units times current market value plus dividends.
Account will be used to record subsidiaries' affiliate payable to
ETR related to the 2013-2015 Long-Term Incentive Plan which
became equity based beginning with the 2012-2014 plan per
Scott Englert. Amanda Menniti is the reconciler.
This account is used to record the liability related to the escrowed
amount for the acquisition of Hinds and Hot Springs plants.
E-9 Page 54 of 99
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41 Schedule E-9
Arkansas Public Service Commission
Chart of Accounts
Minimum Filing Requirements
Partially Projected Test Year Ended
Entergy Arkansas, Inc.
March 31, 2015
Docket No. 15-015-U
(1)
LN
(2)
Account
611
253401
Cash Collateral - L.T. Liab.
612
253A48
Odc-City Water & Light- Rev
613
253A72
Sansouci Substation/IPP
614
253B10
Odc-Duke Ipp Trans Serv Credit
615
253B13
Odc-Wrightsville Pwr Fac Llc
This account contains the activity of transmission service credits
that are owed to this particular IPP generator. The activity could
include additions to the credit eligible balance due to project
construction costs being placed in service and accrued interest, if
applicable. Reductions to this account represent refunds made to
the generator based on transmission reservations.
616
253B72
San Souci - Plum Point IPP
This account contains the activity of transmission service credits
that are owed to this particular IPP generator. The activity could
include additions to the credit eligible balance due to project
construction costs being placed in service and accrued interest, if
applicable. Reductions to this account represent refunds made to
the generator based on transmission reservations.
617
253CIP
CIP Reserve
618
253F16
Oklahoma Gas & Electric/NonIPP
619
253F25
Conway South Sub Switch/NonIPP
620
253F27
Deltic Timber-Kanis Rd/Non/IPP
621
253F30
Ark Childrens Hospital/Non-IPP
622
253F35
N Little Rock-Galloway Non-IPP
623
253F36
Enterprise Products/Non-IPP
624
253F37
City of Paragould / Non-IPP
To record the reserves related to CIP (Critical Infrastructure
Protection).
This account contains the prepaid construction dollars collected
from external load customers. The debits to this account are
either construction costs transferred against the project work in
progress or the related percentage of tax gross-up account
transferred to account 253GXX, monthly as a project expense
balance exists. The credits to this account represent the
prepayments from the generator.
This account will be used as a prepaid CIAC account for the
Conway South Sub Switch addition project in the Asset
Management group.
This account will be used for the TGU associated with the Deltic
Timber Corp - Kanis Road Transmission Line Relocation project in
the Asset Management group.
This account will be used as a prepaid CIAC account for the
Arkansas Children's Hospital (install transfer trip equip) project in
the Asset Management group.
This account will be used as a prepaid CIAC account for the
design and construction of transmission facilities necessary to
accommodate the customer's Point of Delivery. New Account
required for the North Little Rock Electric billing.
This account will be used as a prepaid CIAC account for the
Enterprise Products project (Lynch - Texoma shield pole
relocation) being performed by EAI Grids
This account will be used as a prepaid CIAC account for the City
of Paragould T-Line relocation project being performed by EAI
Grids. New Account required for the City of Paragould T-Line
relocation project billing.
(3)
Account Title
(4)
Account Description
To record counterparty cash collateral deposits, received in
connection with contract performance guarantee.
This account contains the activity of prepaid revenue contract.
The credits represent the prepayment stream and the debits
represent the monthly amortization.
This account contains the prepaid construction dollars collected
from external load customers. The debits to this account are
either construction costs transferred against the project work in
progress or the related percentage of tax gross-up account
transferred to account 253DXX, monthly as a project expense
balance exists. The credits to this account represent the
prepayments from the generator.
This account contains the activity of transmission service credits
that are owed to this particular IPP generator. The activity could
include additions to the credit eligible balance due to project
construction costs being placed in service and accrued interest, if
applicable. Reductions to this account represent refunds made to
the generator based on transmission reservations.
E-9 Page 55 of 99
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41 Schedule E-9
Arkansas Public Service Commission
Chart of Accounts
Minimum Filing Requirements
Partially Projected Test Year Ended
Entergy Arkansas, Inc.
March 31, 2015
Docket No. 15-015-U
(1)
LN
(2)
Account
(3)
Account Title
(4)
Account Description
625
253F41
M&A Elect Pwr Coop NON-IPP
626
253F48
SWPP Non-IPP
627
253F49
Paragould LW&Cable Non-IPP
628
253F57
Ark Elec Coop./Non IPP
629
253F63
Ark Elec Coop Corp./Non IPP
This account will be used as a prepaid CIAC account for Facility
Upgrades of Haskell to Woodlawn 115KV transmission line.
630
253F65
Benton Utilities/Non IPP
631
253F67
Martin Oper Partners/Non IPP
632
253F69
AECC-Wrightsville/Non IPP
633
253F72
Conway Corp/Non IPP
634
253G16
Oklahoma Gas & E/Non-IPP TGU
635
253G25
Conway South Sub Switch TGUNIP
636
253G27
Deltic Timber-Kanis Rd/TGU NIP
This account will be used as a prepaid CIAC account to provide
IPC oversite and substation cut-in work for Benton West
Substation.
This account will be used as a prepaid CIAC account to construct
new 115/13.8 substation and 115kv transmission line to service
customer load.
This account will be used as a prepaid CIAC account for
modifying existing metering at the Wrightsville EHV Sub for the
customer.
This account will be used as a prepaid CIAC for the work
associated with the second transformer at Donaghey sub as
defined in the EPC agreement.
This account contains the tax gross-up dollars collected from
external load customers. The credits to this account are
transferred from the prepaid construction account, 253FXX,
monthly as a project expense balance exists. The debits to this
account represent the tax gross-up being taken into income
quarterly.
This account will be used for the Tax Gross-Up (TGU) associated
with the Conway South Sub Switch addition project in the Asset
Management group.New Account required for the Conway South
Sub Switch Addition TGU.
This account will be used for the Tax Gross-Up (TGU) associated
with the Deltic Timber Corp - Kanis Road Transmission Line
Relocation project in the Asset Management group. New Account
required for the Deltic Timber Corp - Kanis Road Transmission
Line Relocation TGU.
637
253G30
Ark Childrens Hosp TGU/Non-IPP
This account will be used for the Tax Gross-Up (TGU) associated
with the Arkansas Children's Hospital (install transfer trip equip)
project in the Asset Management group. New Account required
for the Ark Children's Hospital (install transfer trip equip) TGU.
638
253G35
N Little Rck Elect Non-IPP TGU
This account will be used for the Tax Gross-Up (TGU) associated
with the design and construction of transmission facilities
necessary to accommodate the customer's Point of Delivery. New
Account required for the North Little Rock Electric billing.
639
253G37
City of Paragould TGU /Non-IPP
640
253G41
M&A Elect Pwr Coop Non-IPP TGU
This account will be used for the Tax Gross-Up (TGU) associated
with the City of Paragould T-Line relocation project being
performed by EAI Grids. New Account required for the City of
Paragould T-Line relocation project TGU.
This account will be used as a prepaid Tax Gross-Up (TGU)
account for EPC oversite and Relaying Upgrades and Cut in
Work defined in the facility study.
This account will be used as a prepaid CIAC account for the
Oversite of EPC and the Relaying Upgrade and Cut-In work
definied in the facility study.New Account required for the M&A
Electric Power billing.
This account will be used as a prepaid CIAC account to install a
transfer trip scheme at the Little Rock Kanis Road Substation for
Southwest Power Pool.
This account will be used as a prepaid CIAC for upgrades to the
Transmission system per the PLWC Transmission Service
Agreement (TSA No. 644).
This account will be used as a prepaid CIAC account to modify
existing metering at Magnet Cove EHV station for customer.
E-9 Page 56 of 99
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41 Schedule E-9
Arkansas Public Service Commission
Chart of Accounts
Minimum Filing Requirements
Partially Projected Test Year Ended
Entergy Arkansas, Inc.
March 31, 2015
Docket No. 15-015-U
(1)
LN
(2)
Account
641
253G48
SWPP - Non-IPP TGU
This account will be used for the Tax Gross Up (TGU) associated
with the installation of a transfer trip scheme at the Little Rock
Kanis Road Substation for Southwest Power Pool.
642
253G49
Paragould LW&Cab - Non-IPP TGU
643
253G57
Ark Elec Coop/Non IPP TGU
644
253G63
Ark Elec Coop Corp/Non IPP TGU
645
253G65
Benton Utilities/Non IPP TGU
646
253G67
Martin Oper Partns/Non IPP TGU
647
253G69
AECC Wrightsville/Non IPP TGU
648
253G72
Conway Corp/Non IPP TGU
649
650
253RES
254000
FERC Reserves
Other Regulatory Liabilities
651
254001
Reg Liab-Nqf-Sfas 115-Val Acct
652
254003
Reg Liab-Qf-Sfas 115-Val Acct
653
254004
Reg Liab-Ano 2-Qf-Sfas 115-Val
654
655
254005
254015
Electric Deferred Fuel Ovr Re
Reg Liability - Act 310
656
254016
Capacity Ridr-Over/Under Recov
657
254017
EE Rider - Over/Under Recovery
658
254301
Reg Liability-Fas 109-Federal
This account will be used for the Tax Gross-Up (TGU) associated
with the upgrades to the transmission system per the PLWC
Transmission Service Agreement (TSA No. 644).
This account is used for the Tax Gross Up associated with the
modifying of existing metering at Magnet Cove EHV station for
customer.
This account is used as a prepaid Tax Gross Up (TGU) account
associated with Facilty Upgrades to the Haskel to Woodlawn 115
KV transmission line.
This account is used as a prepaid Tax Gross Up (TGU) account
associated with providing EPC oversite and substation cut-in work
for Benton West Substation.
This account will be used as a prepaid Tax Gross Up (TGU)
account to construct new substation and 115kv transmission line
to serve customer load.
This account will be used as a prepaid Tax Gross Up (TGU)
account for modifying the metering at Wrightsville Sub for the
customer.
This account will be used for the Tax Gross Up (TGU) associated
with the work on the second transformer at Donaghey sub as
defined in the EPC agreement.
This account is used to record FERC-related reserves.
This account shall include the amounts of regulatory liabilities, not
includible in other accounts, imposed on the utility by the
ratemaking actions of regulatory agencies. ( See USOA
Definition No. 30.)
This account is used to record EAI nuclear decommissioning
valuation as per SFAS 115 for nonqualified funds.
This account is used to record EAI nuclear decommissioning
valuation as per SFAS 115 for qualified funds.
This account is used to record EAI nuclear decommissioning
valuation as per SFAS 115 for qualified funds.
This account is used to record over recovery of Deferred Fuel.
This account will be used to accumulate Act 310 surcharge
revenues.
This account is used to record the regulatory liability for the EAI
capacity rider. Account is being set up to move dollars from
Capacity Rider Regulatory Asset (Account 182394). Setting up
254 account to move credit from asset to liability account per
standard practice.
This account will capture the regulatory liability associated with the
Energy Efficiency Over/Under Recovery (Account 1823EE).
Setting up 254 account to move credit from asset to liability per
standard practice.
This account includes the regulatory liability that offsets an equal
and corresponding FAS 109 accumulated deferred income tax.
659
254303
Gg1 Costs Ovr Recovry-Noncurnt
660
254309
Reg. Liab - DOE Settlement
661
25435A
Reg Liab - MISO FTR M-T-M
This account records the mark-to-market impacts associated with
MISO FTR valutions when resulting in a regulatory liability.
662
254381
Over Recovery - MISO Rider
Over recovery of costs associated with the MISO Rider.
(3)
Account Title
(4)
Account Description
This account is used to record the deferral of the non-current
portion of the over and under recoveries of Grand Gulf demand
charges.
This account is used for the regulatory liability related to the spent
nuclear fuel storage cost Dept. of Energy litigation settlement.
E-9 Page 57 of 99
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41 Schedule E-9
Arkansas Public Service Commission
Chart of Accounts
Minimum Filing Requirements
Partially Projected Test Year Ended
Entergy Arkansas, Inc.
March 31, 2015
Docket No. 15-015-U
(1)
LN
(2)
Account
663
254X01
Def Fuel Liab Reclass
664
255000
Accum Def Inv Tax Credit
665
255100
Accum Deferred Itc
This account shall be credited with all investment tax credits
deferred by companies which have elected to follow deferral
accounting, partial or full, rather than recognizing in the income
statement the total benefits of the tax credit as realized.
666
255200
Accum Deferred Itc 3%
667
282111
Liberalized Depreciation-Fed
This account includes the accumulated deferred income tax credit
for vintage years 1962-1970.
This account shall include the federal tax deferrals resulting from
adoption of the principle of comprehensive interperiod income tax
allocation described in General Instruction 18 of the Uniform
System of Accounts which are related to all property other than
accelerated amortization property. This subaccount contains the
federal tax deferrals for property related items related to liberalized
depreciation. This represents the tax effected differences
between tax deductions and book depreciation or amortization on
a tax basis.
668
282112
Liberalized Deprec - State
This account shall include the state tax deferrals resulting from
adoption of the principle of comprehensive interperiod income tax
allocation described in General Instruction 18 of the Uniform
System of Accounts which are related to all property other than
accelerated amortization property. This subaccount contains the
state tax deferrals for property related items related to liberalized
depreciation. This represents the tax effected differences
between tax deductions and book depreciation or amortization on
a tax basis.
669
282117
Section 481A Adj Fed
This account shall include the federal tax deferrals resulting from
adoption of the principle of comprehensive interperiod income tax
allocation described in General Instruction 18 of the Uniform
System of Accounts which are related to all property other than
accelerated amortization property. This subaccount represents
additional prior year depreciation resulting from the filing of Form
3115 for a change in the depreciable lives of assets.
670
282118
Section 481A Adj State
This account shall include the state tax deferrals resulting from
adoption of the principle of comprehensive interperiod income tax
allocation described in General Instruction 18 of the Uniform
System of Accounts which are related to all property other than
accelerated amortization property. This subaccount represents
additional prior year depreciation resulting from the filing of Form
3115 for a change in the depreciable lives of assets.
671
282139
Constr Fund Interest-Fed
This account shall include the federal tax deferrals resulting from
adoption of the principle of comprehensive interperiod income tax
allocation described in General Instruction 18 of the Uniform
System of Accounts which are related to all property other than
accelerated amortization property. This subaccount contains the
federal tax deferrals related to construction fund interest.
(3)
Account Title
(4)
Account Description
Accounts ending in "X01", "X02", "X03", and "X04" were created
for the sole purpose of being able to journalize certain balance
sheet statement reclassifications into the general ledger. These
accounts do not contain any original operational transactions.
They are simply used to modify the balance sheet statement line
item presentations in Entergy's internally generated balance sheet
statements.
This account shall be credited with all investment tax credits
deferred by companies which have elected to follow deferral
accounting, partial or full, rather than recognizing in the income
statement the total benefits of the tax credit as realized.
E-9 Page 58 of 99
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41 Schedule E-9
Arkansas Public Service Commission
Chart of Accounts
Minimum Filing Requirements
Partially Projected Test Year Ended
Entergy Arkansas, Inc.
March 31, 2015
Docket No. 15-015-U
(1)
LN
(2)
Account
672
282140
Constr Fund Interest-St
This account shall include the state tax deferrals resulting from
adoption of the principle of comprehensive interperiod income tax
allocation described in General Instruction 18 of the Uniform
System of Accounts which are related to all property other than
accelerated amortization property. This subaccount contains the
state tax deferrals related to construction fund interest.
673
282141
Cost Of Money On Aecc - Fed
674
282142
Cost Of Money On Aecc - St
675
282167
Taxes & Pensions Cap.- Fed
This account shall include the federal tax deferrals resulting from
adoption of the principle of comprehensive interperiod income tax
allocation described in General Instruction 18 of the Uniform
System of Accounts which are related to all property other than
accelerated amortization property. This subaccount contains the
federal tax deferrals related to a difference between the book and
tax basis of plant.
This account shall include the state tax deferrals resulting from
adoption of the principle of comprehensive interperiod income tax
allocation described in General Instruction 18 of the Uniform
System of Accounts which are related to all property other than
accelerated amortization property. This subaccount contains the
state tax deferrals related to a difference between the book and
tax basis of plant.
This account shall include the federal tax deferrals resulting from
adoption of the principle of comprehensive interperiod income tax
allocation described in General Instruction 18 of the Uniform
System of Accounts which are related to all property other than
accelerated amortization property. This subaccount contains the
federal tax deferrals related to taxes and pensions capitalized.
676
282168
Taxes & Pensions Cap - State
This account shall include the state tax deferrals resulting from
adoption of the principle of comprehensive interperiod income tax
allocation described in General Instruction 18 of the Uniform
System of Accounts which are related to all property other than
accelerated amortization property. This subaccount contains the
state tax deferrals related to taxes and pensions capitalized.
677
282175
Afdc Book Only Gross - Fed
678
282176
Afdc Book Only Gross - State
679
282211
Nuclear Fuel - Federal
This account shall include the federal tax deferrals resulting from
adoption of the principle of comprehensive interperiod income tax
allocation described in General Instruction 18 of the Uniform
System of Accounts which are related to all property other than
accelerated amortization property. This subaccount contains the
federal tax deferrals related to the allowance for debt funds used
during construction.
This account shall include the state tax deferrals resulting from
adoption of the principle of comprehensive interperiod income tax
allocation described in General Instruction 18 of the Uniform
System of Accounts which are related to all property other than
accelerated amortization property. This subaccount contains the
state tax deferrals related to the allowance for debt funds used
during construction.
This account shall include the federal tax deferrals resulting from
adoption of the principle of comprehensive interperiod income tax
allocation described in General Instruction 18 of the Uniform
System of Accounts which are related to all property other than
accelerated amortization property. This subaccount contains the
federal tax deferrals related to nuclear fuel.
(3)
Account Title
(4)
Account Description
E-9 Page 59 of 99
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41 Schedule E-9
Arkansas Public Service Commission
Chart of Accounts
Minimum Filing Requirements
Partially Projected Test Year Ended
Entergy Arkansas, Inc.
March 31, 2015
Docket No. 15-015-U
(1)
LN
(2)
Account
680
282212
Nuclear Fuel - State
This account shall include the state tax deferrals resulting from
adoption of the principle of comprehensive interperiod income tax
allocation described in General Instruction 18 of the Uniform
System of Accounts which are related to all property other than
accelerated amortization property. This subaccount contains the
state tax deferrals related to nuclear fuel.
681
282217
Coal Car - Fed
This account shall include the federal tax deferrals resulting from
adoption of the principle of comprehensive interperiod income tax
allocation described in General Instruction 18 of the Uniform
System of Accounts which are related to all property other than
accelerated amortization property. This subaccount contains the
federal tax deferrals related to coal cars.
682
282218
Coal Car - State
This account shall include the state tax deferrals resulting from
adoption of the principle of comprehensive interperiod income tax
allocation described in General Instruction 18 of the Uniform
System of Accounts which are related to all property other than
accelerated amortization property. This subaccount contains the
state tax deferrals related to coal cars.
683
282221
Fiber Optics-Fed
This account shall include the federal tax deferrals resulting from
adoption of the principle of comprehensive interperiod income tax
allocation described in General Instruction 18 of the Uniform
System of Accounts which are related to all property other than
accelerated amortization property. This subaccount contains the
federal tax deferrals related to fiber optics. This represents the
differences for the tax deferral of book income related to the
involuntary conversion of microwave equipment.
684
282222
Fiber Optics - State
This account shall include the state tax deferrals resulting from
adoption of the principle of comprehensive interperiod income tax
allocation described in General Instruction 18 of the Uniform
System of Accounts which are related to all property other than
accelerated amortization property. This subaccount contains the
state tax deferrals related to fiber optics. This represents the
differences for the tax deferral of book income related to the
involuntary conversion of microwave equipment.
685
282223
Repairs & Maint Exp - Federal
This account shall include the federal tax deferrals resulting from
adoption of the principle of comprehensive interperiod income tax
allocation described in General Instruction 18 of the Uniform
System of Accounts which are related to all property other than
accelerated amortization property. This subaccount contains the
federal tax deferrals related to repairs and maintenance expense.
This represents the tax deduction of project costs and vegetation
management costs capitalized on the books.
686
282224
Repairs & Maint Exp - State
This account shall include the state tax deferrals resulting from
adoption of the principle of comprehensive interperiod income tax
allocation described in General Instruction 18 of the Uniform
System of Accounts which are related to all property other than
accelerated amortization property. This subaccount contains the
state tax deferrals related to repairs and maintenance expense.
This represents the tax deduction of project costs and vegetation
management costs capitalized on the books.
(3)
Account Title
(4)
Account Description
E-9 Page 60 of 99
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41 Schedule E-9
Arkansas Public Service Commission
Chart of Accounts
Minimum Filing Requirements
Partially Projected Test Year Ended
Entergy Arkansas, Inc.
March 31, 2015
Docket No. 15-015-U
(1)
LN
(2)
Account
687
282241
R&E Deduction - Fed
This account shall include the federal tax deferrals resulting from
adoption of the principle of comprehensive interperiod income tax
allocation described in General Instruction 18 of the Uniform
System of Accounts which are related to all property other than
accelerated amortization property. This subaccount contains the
federal tax deferrals related to property related research and
experimental expenditures. This represents the accelerated tax
deduction for projects that qualify for research and experimental
when incurred but are capitalized for books.
688
282242
R&E Deduction - St
This account shall include the state tax deferrals resulting from
adoption of the principle of comprehensive interperiod income tax
allocation described in General Instruction 18 of the Uniform
System of Accounts which are related to all property other than
accelerated amortization property. This subaccount contains the
state tax deferrals related to property related research and
experimental expenditures. This represents the accelerated tax
deduction for projects that qualify for research and experimental
when incurred but are capitalized for books.
689
282245
Warranty Expense - Federal
This account shall include the federal tax deferrals resulting from
adoption of the principle of comprehensive interperiod income tax
allocation described in General Instruction 18 of the Uniform
System of Accounts which are related to all property other than
accelerated amortization property. This subaccount contains the
federal tax deferrals related to warranty expense. This represents
the accelerated tax deduction for project costs that are deducted
as warranty expense, but are capitalized for books.
690
282246
Warranty Expense - State
This account shall include the state tax deferrals resulting from
adoption of the principle of comprehensive interperiod income tax
allocation described in General Instruction 18 of the Uniform
System of Accounts which are related to all property other than
accelerated amortization property. This subaccount contains the
state tax deferrals related to warranty expense. This represents
the accelerated tax deduction for project costs that are deducted
as warranty expense, but are capitalized for books.
691
282281
Sfi Coal Program - Fed
This account shall include the federal tax deferrals resulting from
adoption of the principle of comprehensive interperiod income tax
allocation described in General Instruction 18 of the Uniform
System of Accounts which are related to all property other than
accelerated amortization property. This subaccount contains the
federal tax deferrals related to the SFI coal program.
692
282311
Int Inc Pol Control Bonds-Fed
693
282312
Int Inc Pol Control Bonds-St
This account shall include the federal tax deferrals resulting from
adoption of the principle of comprehensive interperiod income tax
allocation described in General Instruction 18 of the Uniform
System of Accounts which are related to all property other than
accelerated amortization property. This subaccount contains the
federal tax deferrals related to a difference between the book and
tax basis of plant.
This account shall include the state tax deferrals resulting from
adoption of the principle of comprehensive interperiod income tax
allocation described in General Instruction 18 of the Uniform
System of Accounts which are related to all property other than
accelerated amortization property. This subaccount contains the
state tax deferrals related to a difference between the book and
tax basis of plant.
(3)
Account Title
(4)
Account Description
E-9 Page 61 of 99
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41 Schedule E-9
Arkansas Public Service Commission
Chart of Accounts
Minimum Filing Requirements
Partially Projected Test Year Ended
Entergy Arkansas, Inc.
March 31, 2015
Docket No. 15-015-U
(1)
LN
(2)
Account
694
282331
Misc Intangible Plant-Federal
695
282332
Misc Intangible Plant-State
696
282341
Interest - Deferred Pay - Fed
697
282342
Interest - Deferred Pay - St
698
282351
Tax Int (Avoided Cost)-Fed
699
282352
Tax Int (Avoided Cost) - St
700
282371
Cont In Aid Of Constr - Fed
701
282372
Cont In Aid Of Constr - State
(3)
Account Title
(4)
Account Description
This account shall include the federal tax deferrals resulting from
adoption of the principle of comprehensive interperiod income tax
allocation described in General Instruction 18 of the Uniform
System of Accounts which are related to all property other than
accelerated amortization property. This subaccount contains the
federal tax deferrals related to interest income for miscellaneous
intangible plant.
This account shall include the state tax deferrals resulting from
adoption of the principle of comprehensive interperiod income tax
allocation described in General Instruction 18 of the Uniform
System of Accounts which are related to all property other than
accelerated amortization property. This subaccount contains the
state tax deferrals related to interest income for miscellaneous
intangible plant.
This account shall include the federal tax deferrals resulting from
adoption of the principle of comprehensive interperiod income tax
allocation described in General Instruction 18 of the Uniform
System of Accounts which are related to all property other than
accelerated amortization property. This subaccount contains the
federal tax deferrals related to a difference between the book and
tax basis of plant.
This account shall include the state tax deferrals resulting from
adoption of the principle of comprehensive interperiod income tax
allocation described in General Instruction 18 of the Uniform
System of Accounts which are related to all property other than
accelerated amortization property. This subaccount contains the
state tax deferrals related to a difference between the book and
tax basis of plant.
This account shall include the federal tax deferrals resulting from
adoption of the principle of comprehensive interperiod income tax
allocation described in General Instruction 18 of the Uniform
System of Accounts which are related to all property other than
accelerated amortization property. This represents interest
capitalized for tax purposes on non-transitional construction
projects. Beginning with tax year 1987, interest incurred during
the construction of an asset must be capitalized. For book
purposes, interest is capitalized via the debt component of
AFUDC.
This account shall include the state tax deferrals resulting from
adoption of the principle of comprehensive interperiod income tax
allocation described in General Instruction 18 of the Uniform
System of Accounts which are related to all property other than
accelerated amortization property. This represents interest
capitalized for tax purposes on non-transitional construction
projects. Beginning with tax year 1987, interest incurred during
the construction of an asset must be capitalized. For book
purposes, interest is capitalized via the debt component of
AFUDC.
This account shall include the federal tax deferrals resulting from
adoption of the principle of comprehensive interperiod income tax
allocation described in General Instruction 18 of the Uniform
System of Accounts which are related to all property other than
accelerated amortization property. This subaccount contains the
federal tax deferrals related to contributions in aid of construction.
This account shall include the state tax deferrals resulting from
adoption of the principle of comprehensive interperiod income tax
allocation described in General Instruction 18 of the Uniform
System of Accounts which are related to all property other than
accelerated amortization property. This subaccount contains the
state tax deferrals related to contributions in aid of construction.
E-9 Page 62 of 99
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41 Schedule E-9
Arkansas Public Service Commission
Chart of Accounts
Minimum Filing Requirements
Partially Projected Test Year Ended
Entergy Arkansas, Inc.
March 31, 2015
Docket No. 15-015-U
(1)
LN
(2)
Account
702
282381
Construction Power - Fed
This account shall include the federal tax deferrals resulting from
adoption of the principle of comprehensive interperiod income tax
allocation described in General Instruction 18 of the Uniform
System of Accounts which are related to all property other than
accelerated amortization property. This subaccount contains the
federal tax deferrals related to construction power.
703
282382
Construction Power - State
This account shall include the state tax deferrals resulting from
adoption of the principle of comprehensive interperiod income tax
allocation described in General Instruction 18 of the Uniform
System of Accounts which are related to all property other than
accelerated amortization property. This subaccount contains the
state tax deferrals related to construction power.
704
282391
Ises Book Deprec Cap - Fed
This account shall include the federal tax deferrals resulting from
adoption of the principle of comprehensive interperiod income tax
allocation described in General Instruction 18 of the Uniform
System of Accounts which are related to all property other than
accelerated amortization property. This subaccount contains the
federal tax deferrals related to ISES book depreciation capitalized.
705
282392
Ises Book Deprec Cap - State
This account shall include the state tax deferrals resulting from
adoption of the principle of comprehensive interperiod income tax
allocation described in General Instruction 18 of the Uniform
System of Accounts which are related to all property other than
accelerated amortization property. This subaccount contains the
state tax deferrals related to ISES book depreciation capitalized.
706
282455
Business Dev Costs Cap- Fed
707
282456
Business Dev Costs Cap- St
708
282461
Computer Software Cap - Fed
To record federal deferred taxes on the difference between book
and tax recordation of business development costs. For tax, costs
are expensed.
To record state deferred taxes on the difference between book
and tax recordation of business development costs. For tax, costs
are expensed.
This account shall include the federal tax deferrals resulting from
adoption of the principle of comprehensive interperiod income tax
allocation described in General Instruction 18 of the Uniform
System of Accounts which are related to all property other than
accelerated amortization property. This subaccount contains the
federal tax deferrals related to computer software capitalized.
709
282462
Computer Software Cap - State
This account shall include the state tax deferrals resulting from
adoption of the principle of comprehensive interperiod income tax
allocation described in General Instruction 18 of the Uniform
System of Accounts which are related to all property other than
accelerated amortization property. This subaccount contains the
state tax deferrals related to computer software capitalized.
710
282465
Ises Synchronization Adj - Fed
711
282466
Ises Synchronization Adj - St
This account shall include the federal tax deferrals resulting from
adoption of the principle of comprehensive interperiod income tax
allocation described in General Instruction 18 of the Uniform
System of Accounts which are related to all property other than
accelerated amortization property. This subaccount contains the
federal tax deferrals related to the ISES synchronization
adjustment.
This account shall include the state tax deferrals resulting from
adoption of the principle of comprehensive interperiod income tax
allocation described in General Instruction 18 of the Uniform
System of Accounts which are related to all property other than
accelerated amortization property. This subaccount contains the
state tax deferrals related to the ISES synchronization adjustment.
(3)
Account Title
(4)
Account Description
E-9 Page 63 of 99
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41 Schedule E-9
Arkansas Public Service Commission
Chart of Accounts
Minimum Filing Requirements
Partially Projected Test Year Ended
Entergy Arkansas, Inc.
March 31, 2015
Docket No. 15-015-U
(1)
LN
(2)
Account
712
282475
Contra Securitization -Federal
This account shall include the federal tax deferrals resulting from
adoption of the principle of comprehensive interperiod income tax
allocation described in General Instruction 18 of the Uniform
System of Accounts which are related to all property other than
accelerated amortization property. This subaccount contains the
federal tax deferrals related to the contra securitization.
713
282476
Contra Securitization - State
This account shall include the state tax deferrals resulting from
adoption of the principle of comprehensive interperiod income tax
allocation described in General Instruction 18 of the Uniform
System of Accounts which are related to all property other than
accelerated amortization property. This subaccount contains the
state tax deferrals related to the contra securitization.
714
282481
Full Norm Of Prod Plant - Fed
715
282482
Full Norm Of Prod Plant - St
716
282533
Casualty Loss Deduction-Fed
717
282534
Casualty Loss Deduction-St
718
282701
Fas 109 Adjustment - Fed
This account shall include the federal tax deferrals resulting from
adoption of the principle of comprehensive interperiod income tax
allocation described in General Instruction 18 of the Uniform
System of Accounts which are related to all property other than
accelerated amortization property. This subaccount contains the
federal tax deferrals related to the full normalization of production
plant.
This account shall include the state tax deferrals resulting from
adoption of the principle of comprehensive interperiod income tax
allocation described in General Instruction 18 of the Uniform
System of Accounts which are related to all property other than
accelerated amortization property. This subaccount contains the
state tax deferrals related to the full normalization of production
plant.
This account shall include the federal tax deferrals resulting from
adoption of the principle of comprehensive interperiod income tax
allocation described in General Instruction 18 of the Uniform
System of Accounts which are related to all property other than
accelerated amortization property. This subaccount contains the
federal tax deferrals related to the property related casualty losses
deduction.
This account shall include the state tax deferrals resulting from
adoption of the principle of comprehensive interperiod income tax
allocation described in General Instruction 18 of the Uniform
System of Accounts which are related to all property other than
accelerated amortization property. This subaccount contains the
state tax deferrals related to the property related casualty losses
deduction.
This account shall include the federal tax deferrals resulting from
adoption of the principle of comprehensive interperiod income tax
allocation described in General Instruction 18 of the Uniform
System of Accounts which are related to all property other than
accelerated amortization property. This subaccount contains the
federal tax deferrals related to the Statement of Financial
Accounting Standards 109 adjustment.
719
282702
Fas 109 Adjustment - State
(3)
Account Title
(4)
Account Description
This account shall include the state tax deferrals resulting from
adoption of the principle of comprehensive interperiod income tax
allocation described in General Instruction 18 of the Uniform
System of Accounts which are related to all property other than
accelerated amortization property. This subaccount contains the
state tax deferrals related to the Statement of Financial
Accounting Standards 109 adjustment.
E-9 Page 64 of 99
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41 Schedule E-9
Arkansas Public Service Commission
Chart of Accounts
Minimum Filing Requirements
Partially Projected Test Year Ended
Entergy Arkansas, Inc.
March 31, 2015
Docket No. 15-015-U
(1)
LN
(2)
Account
720
282901
263A Method Change-DSC - Fed
This account shall include the federal tax deferrals resulting from
adoption of the principle of comprehensive interperiod income tax
allocation described in General Instruction 18 of the Uniform
System of Accounts which are related to all property other than
accelerated amortization property. This subaccount contains the
federal tax deferrals related to the change in accounting method
for 263A deductible service costs.
721
282902
263A Method Change - DSC-State
This account shall include the state tax deferrals resulting from
adoption of the principle of comprehensive interperiod income tax
allocation described in General Instruction 18 of the Uniform
System of Accounts which are related to all property other than
accelerated amortization property. This subaccount contains the
state tax deferrals related to the change in accounting method for
263A deductible service costs.
722
282903
Units of Production Ded - Fed
723
282904
Units of Production Ded - St
724
282905
Tangible Prop Regs-481 Adj-Fed
725
282906
Tangible Prop Regs-481-St
726
282907
Unit of Property Ded-Trans-Fed
727
282908
Unit of Property Ded-Trans-St
728
282975
Depreciation Expense - Fed
This account shall include the federal tax deferrals resulting from
adoption of the principle of comprehensive interperiod income tax
allocation described in General Instruction 18 of the Uniform
System of Accounts which are related to all property other than
accelerated amortization property. This subaccount contains the
federal tax deferrals related to the units of property change in
accounting method.
This account shall include the state tax deferrals resulting from
adoption of the principle of comprehensive interperiod income tax
allocation described in General Instruction 18 of the Uniform
System of Accounts which are related to all property other than
accelerated amortization property. This subaccount contains the
state tax deferrals related to the units of property change in
accounting method.
To record federal accumulated deferred taxes related to the units
of production deduction. This is considered a current
accumulated deferred income tax account.
To record state accumulated deferred taxes related to the units of
production deduction. This is considered a current accumulated
deferred income tax account.
To record federal accumulated deferred taxes related to the units
of property deduction for Transmission.
To record state accumulated deferred taxes related to the units of
property deduction for Transmission.
This account shall include the federal tax deferrals resulting from
adoption of the principle of comprehensive interperiod income tax
allocation described in General Instruction 18 of the Uniform
System of Accounts which are related to all property other than
accelerated amortization property. This subaccount contains the
federal tax deferrals related to depreciation expense.
729
282976
Depreciation Expense - State
This account shall include the state tax deferrals resulting from
adoption of the principle of comprehensive interperiod income tax
allocation described in General Instruction 18 of the Uniform
System of Accounts which are related to all property other than
accelerated amortization property. This subaccount contains the
state tax deferrals related to depreciation expense.
730
282F48
FIN 48 Adjustment
This account was used to record FIN 48 accumulated deferred
income tax.
(3)
Account Title
(4)
Account Description
E-9 Page 65 of 99
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41 Schedule E-9
Arkansas Public Service Commission
Chart of Accounts
Minimum Filing Requirements
Partially Projected Test Year Ended
Entergy Arkansas, Inc.
March 31, 2015
Docket No. 15-015-U
(1)
LN
(2)
Account
731
283151
Regulatory Asset - Federal
This account shall include the federal tax deferrals resulting from
adoption of the principle of comprehensive interperiod income tax
allocation described in General Instruction 18 of the Uniform
System of Accounts other than those deferrals which are
includible in Account 281 or Account 282. This subaccount
contains the federal tax deferrals related to regulatory assets.
732
283152
Regulatory Asset - State
This account shall include the state tax deferrals resulting from
adoption of the principle of comprehensive interperiod income tax
allocation described in General Instruction 18 of the Uniform
System of Accounts other than those deferrals which are
includible in Account 281 or Account 282. This subaccount
contains the state tax deferrals related to regulatory assets.
733
283157
Regulatory Asset-MISO-Fed
734
283158
Regulatory Asset-MISO-State
735
283165
Syst Agrmt Equal Reg Asset-Fed
736
283166
Syst Agrmt Equal Reg Asset-St
737
283181
Maint/Refueling - Fed
This account shall include the federal tax deferrals resulting from
adoption of the principle of comprehensive interperiod income tax
allocation described in General Instruction 18 of the Uniform
System of Accounts other than those deferrals which are
includible in Account 281 or Account 282. This subaccount
contains the federal tax deferrals related to regulatory assets for
MISO costs.
This account shall include the state tax deferrals resulting from
adoption of the principle of comprehensive interperiod income tax
allocation described in General Instruction 18 of the UsofA other
than those deferrals which are includible in Accounts 281 and
282. This subaccount contains the state tax dererrals relating to
reg assets for MISO costs.
This account shall include the federal tax deferrals resulting from
adoption of the principle of comprehensive interperiod income tax
allocation described in General Instruction 18 of the Uniform
System of Accounts other than those deferrals which are
includible in Account 281 or Account 282. This subaccount
contains the federal tax deferrals related to the System
Agreement Equalization regulatory asset.
This account shall include the state tax deferrals resulting from
adoption of the principle of comprehensive interperiod income tax
allocation described in General Instruction 18 of the Uniform
System of Accounts other than those deferrals which are
includible in Account 281 or Account 282. This subaccount
contains the state tax deferrals related to the System Agreement
Equalization regulatory asset.
This account shall include the federal tax deferrals resulting from
adoption of the principle of comprehensive interperiod income tax
allocation described in General Instruction 18 of the Uniform
System of Accounts other than those deferrals which are
includible in Account 281 or Account 282. This subaccount
contains the federal tax deferrals related to maintenance refueling.
738
283182
Maint/Refueling - St
This account shall include the state tax deferrals resulting from
adoption of the principle of comprehensive interperiod income tax
allocation described in General Instruction 18 of the Uniform
System of Accounts other than those deferrals which are
includible in Account 281 or Account 282. This subaccount
contains the state tax deferrals related to maintenance refueling.
739
283213
SFAS 158 Def Tax Liability-Fed
This account shall include the federal tax deferrals resulting from
adoption of the principle of comprehensive interperiod income tax
allocation described in General Instruction 18 of the Uniform
System of Accounts other than those deferrals which are
includible in Account 281 or Account 282. This subaccount
contains the federal tax deferrals on post retirement benefit plan
regulatory assets.
(3)
Account Title
(4)
Account Description
E-9 Page 66 of 99
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41 Schedule E-9
Arkansas Public Service Commission
Chart of Accounts
Minimum Filing Requirements
Partially Projected Test Year Ended
Entergy Arkansas, Inc.
March 31, 2015
Docket No. 15-015-U
(1)
LN
(2)
Account
740
283214
SFAS 158 Def Tax Liability-St
741
283221
Bond Reacquisition Loss - Fed
742
283222
Bond Reacquisition Loss - St
This account shall include the state tax deferrals resulting from
adoption of the principle of comprehensive interperiod income tax
allocation described in General Instruction 18 of the Uniform
System of Accounts other than those deferrals which are
includible in Account 281 or Account 282. This represents the
difference for losses on reaquired debt that are amortized for
books and deducted for tax in the year of reacquisition.
743
283225
Section 475 Adjustment-Fed
744
283226
Section 475 Adjustment-St
745
283243
Reg. Asset-Low Lev Rad Wst-Fed
This account shall include the federal tax deferrals resulting from
adoption of the principle of comprehensive interperiod income tax
allocation described in General Instruction 18 of the Uniform
System of Accounts other than those deferrals which are
includible in Account 281 or Account 282. This represents the
difference on the taxable income or tax deduction on the mark-tomarket of certain contracts.
This account shall include the state tax deferrals resulting from
adoption of the principle of comprehensive interperiod income tax
allocation described in General Instruction 18 of the Uniform
System of Accounts other than those deferrals which are
includible in Account 281 or Account 282. This represents the
difference on the taxable income or tax deduction on the mark-tomarket of certain contracts.
To record federal deferred taxes on the difference between book
and tax treatment associated with payments made to Texas to
establish a disposal facility of Fuel (Texas COMPACT).
746
747
283244
283245
Reg. Asset-Low Lev Rad Wst-St
Distribution Maintenance - Fed
748
283246
Distribution Maintenance - St
(3)
Account Title
(4)
Account Description
This account shall include the state tax deferrals resulting from
adoption of the principle of comprehensive interperiod income tax
allocation described in General Instruction 18 of the Uniform
System of Accounts other than those deferrals which are
includible in Account 281 or Account 282. This subaccount
contains the state tax deferrals related to the Statements of
Financial Accounting Standards 158 deferred tax liability. This
subaccount contains the federal tax deferrals on post retirement
benefit plan regulatory assets.
This account shall include the federal tax deferrals resulting from
adoption of the principle of comprehensive interperiod income tax
allocation described in General Instruction 18 of the Uniform
System of Accounts other than those deferrals which are
includible in Account 281 or Account 282. This represents the
difference for losses on reaquired debt that are amortized for
books and deducted for tax in the year of reacquisition.
To book deferred taxes related to low level rad waste.
This account shall include the federal tax deferrals resulting from
adoption of the principle of comprehensive interperiod income tax
allocation described in General Instruction 18 of the Uniform
System of Accounts other than those deferrals which are
includible in Account 281 or Account 282. This represents the
differences for certain costs capitalized for books and deducted for
tax.
This account shall include the state tax deferrals resulting from
adoption of the principle of comprehensive interperiod income tax
allocation described in General Instruction 18 of the Uniform
System of Accounts other than those deferrals which are
includible in Account 281 or Account 282. This represents the
differences for certain costs capitalized for books and deducted for
tax.
E-9 Page 67 of 99
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41 Schedule E-9
Arkansas Public Service Commission
Chart of Accounts
Minimum Filing Requirements
Partially Projected Test Year Ended
Entergy Arkansas, Inc.
March 31, 2015
Docket No. 15-015-U
(1)
LN
(2)
Account
749
283247
Transco Costs - Federal
750
283248
Transco Costs - State
751
283249
Deferred Storm Costs - Federal
752
283250
Deferred Storm costs - State
This account shall include the federal tax deferrals resulting from
adoption of the principle of comprehensive interperiod income tax
allocation described in General Instruction 18 of the Uniform
System of Accounts other than those deferrals which are
includible in Account 281 or Account 282. This represents the
difference for certain storm costs deferred on the books.
753
283301
Regulatory Asset-HCM-Fed
754
283302
Regulatory Asset-HCM-State
755
283305
Regulatory Asset-MOARK-Fed
756
283306
Regulatory Asset-MOARK-State
757
283325
Tcby Tower (Cadc)-Fed
758
283326
Tcby Tower (Cadc)-St
759
283345
Misc Cap Costs-Fed
760
283346
Misc Cap Costs-State
761
283357
Tca - 30 Year Retail - Federal
To separate accumulated Federal deferred taxes for regulatory
assets related to HCM costs.
To separate accumulated State deferred taxes for regulatory
assets related to HCM costs.
To separate accumulated Federal deferred taxes for regulatory
assets related to MOARK costs.
To separate accumulated State deferred taxes for regulatory
assets related to MOARK costs.
This account shall include the federal tax deferrals resulting from
adoption of the principle of comprehensive interperiod income tax
allocation described in General Instruction 18 of the Uniform
System of Accounts other than those deferrals which are
includible in Account 281 or Account 282. This represents the
difference for CADC partnership deductions in excess of
partnership income.
This account shall include the federal tax deferrals resulting from
adoption of the principle of comprehensive interperiod income tax
allocation described in General Instruction 18 of the Uniform
System of Accounts other than those deferrals which are
includible in Account 281 or Account 282. This represents the
difference for CADC partnership deductions in excess of
partnership income.
To record federal deferred taxes on the difference between book
and tax treatment for deferred debits related to 263A.
To record state deferred taxes on the difference between book
and tax treatment for deferred debits related to 263A.
This account shall include the federal tax deferrals resulting from
adoption of the principle of comprehensive interperiod income tax
allocation described in General Instruction 18 of the Uniform
System of Accounts other than those deferrals which are
includible in Account 281 or Account 282. This subaccount of 283
accounts for the federal taxes related to costs recorded in FERC
account 182357 - Reg Asset 30yr Retail.
(3)
Account Title
(4)
Account Description
This account shall include the federal tax deferrals resulting from
adoption of the principle of comprehensive interperiod income tax
allocation described in General Instruction 18 of the Uniform
System of Accounts other than those deferrals which are
includible in Account 281 or Account 282. This represents the
TRANSCO and transition to competition costs capitalized for
books and the reversal of book amortization.
This account shall include the state tax deferrals resulting from
adoption of the principle of comprehensive interperiod income tax
allocation described in General Instruction 18 of the Uniform
System of Accounts other than those deferrals which are
includible in Account 281 or Account 282. This represents the
TRANSCO and transition to competition costs capitalized for
books and the reversal of book amortization.
This account shall include the federal tax deferrals resulting from
adoption of the principle of comprehensive interperiod income tax
allocation described in General Instruction 18 of the Uniform
System of Accounts other than those deferrals which are
includible in Account 281 or Account 282. This represents the
difference for certain storm costs deferred on the books.
E-9 Page 68 of 99
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41 Schedule E-9
Arkansas Public Service Commission
Chart of Accounts
Minimum Filing Requirements
Partially Projected Test Year Ended
Entergy Arkansas, Inc.
March 31, 2015
Docket No. 15-015-U
(1)
LN
(2)
Account
762
283358
Tca - 30 Year Retail - State
This account shall include the federal tax deferrals resulting from
adoption of the principle of comprehensive interperiod income tax
allocation described in General Instruction 18 of the Uniform
System of Accounts other than those deferrals which are
includible in Account 281 or Account 282. This subaccount of 283
accounts for the state taxes related to costs recorded in FERC
account 182357 - Reg Asset 30yr Retail.
763
283361
Prepaid Expenses Federal
764
283362
Prepaid Expenses State
765
283371
Decon & Decomm Fund - Fed
This account shall include the federal tax deferrals resulting from
adoption of the principle of comprehensive interperiod income tax
allocation described in General Instruction 18 of the Uniform
System of Accounts other than those deferrals which are
includible in Account 281 or Account 282. This represents the
differences for prepaid expenses amortized for books but
deducted for tax.
This account shall include the state tax deferrals resulting from
adoption of the principle of comprehensive interperiod income tax
allocation described in General Instruction 18 of the Uniform
System of Accounts other than those deferrals which are
includible in Account 281 or Account 282. This represents the
differences for prepaid expenses amortized for books but
deducted for tax.
This account shall include the federal tax deferrals resulting from
adoption of the principle of comprehensive interperiod income tax
allocation described in General Instruction 18 of the Uniform
System of Accounts other than those deferrals which are
includible in Account 281 or Account 282. This subaccount of 283
accounts for the federal taxes related to D&D assessments by the
DOE recorded in FERC account 182300 - DOE D&D Fee and
FERC account 228402 - Decomm & Decontamination.
766
283372
Decon & Decomm Fund - St
This account shall include the federal tax deferrals resulting from
adoption of the principle of comprehensive interperiod income tax
allocation described in General Instruction 18 of the Uniform
System of Accounts other than those deferrals which are
includible in Account 281 or Account 282. This subaccount of 283
accounts for the state taxes related to D&D assessments by the
DOE recorded in FERC account 182300 - DOE D&D Fee and
FERC account 228402 - Decomm & Decontamination.
767
283511
Tax Gain - Ises Sale - Fed
768
283512
Tax Gain - Ises Sale - State
769
283517
Tax Gain - Sale Of Ang - Fed
This account recorded federal accumulated deferred income taxes
on the tax gain on a sale of Independence Steam Electric Station
assets.
This account recorded state accumulated deferred income taxes
on the tax gain on a sale of Independence Steam Electric Station
assets.
This account recorded federal accumulated deferred income taxes
on the tax gain on the sale of Associated Natural Gas Company.
770
283518
Tax Gain - Sale Of Ang - St
This account recorded state accumulated deferred income taxes
on the tax gain on the sale of Associated Natural Gas Company.
771
283701
Fas 109 Adjustment - Fed
This account shall include the federal tax deferrals resulting from
adoption of the principle of comprehensive interperiod income tax
allocation described in General Instruction 18 of the Uniform
System of Accounts other than those deferrals which are
includible in Account 281 or Account 282. This represents
additional deferred taxes on temporary differences due to
implementation and restatement for SFAS 109.
(3)
Account Title
(4)
Account Description
E-9 Page 69 of 99
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41 Schedule E-9
Arkansas Public Service Commission
Chart of Accounts
Minimum Filing Requirements
Partially Projected Test Year Ended
Entergy Arkansas, Inc.
March 31, 2015
Docket No. 15-015-U
(1)
LN
(2)
Account
772
283702
Fas 109 Adjustment - State
773
283901
263A Method Change - Federal
774
283902
263A Method Change - State
775
283F48
FIN 48 adjustment
776
283X01
ADIT Fed Current Liab Reclass
777
283X02
ADIT - ST current liab reclass
(3)
Account Title
778
Electric Plant Accounts
779
Intangible Plant
780
301
Organization
(4)
Account Description
This account shall include the state tax deferrals resulting from
adoption of the principle of comprehensive interperiod income tax
allocation described in General Instruction 18 of the Uniform
System of Accounts other than those deferrals which are
includible in Account 281 or Account 282. This represents
additional deferred taxes on temporary differences due to
implementation and restatement for SFAS 109.
This account shall include the federal tax deferrals resulting from
adoption of the principle of comprehensive interperiod income tax
allocation described in General Instruction 18 of the Uniform
System of Accounts other than those deferrals which are
includible in Account 281 or Account 282. This subaccount
contains the federal tax deferrals related to the change in
accounting method for 263A except for the uncertain amount
included in account 283F48.
This account shall include the state tax deferrals resulting from
adoption of the principle of comprehensive interperiod income tax
allocation described in General Instruction 18 of the Uniform
System of Accounts other than those deferrals which are
includible in Account 281 or Account 282. This subaccount
contains the state tax deferrals related to the change in
accounting method for 263A.
This account shall include the federal tax deferrals resulting from
adoption of the principle of comprehensive interperiod income tax
allocation described in General Instruction 18 of the Uniform
System of Accounts other than those deferrals which are
includible in Account 281 or Account 282. This subaccount
contains the federal tax deferrals related to the change in
accounting method for 263A that are uncertain per FIN 48.
Accounts ending in "X01", "X02", "X03", and "X04" were created
for the sole purpose of being able to journalize certain balance
sheet statement reclassifications into the general ledger. These
accounts do not contain any original operational transactions.
They are simply used to modify the balance sheet statement line
item presentations in our internally generated balance sheet
statements.
Accounts ending in "X01", "X02", "X03", and "X04" were created
for the sole purpose of being able to journalize certain balance
sheet statement reclassifications into the general ledger. These
accounts do not contain any original operational transactions.
They are simply used to modify the balance sheet statement line
item presentations in our internally generated balance sheet
statements.
This account shall include all fees paid to federal or state
governments for the privilege of incorporation and expenditures
incident to organizing the corporation, partnership, or other
enterprise and putting it into readiness to do business.
E-9 Page 70 of 99
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41 Schedule E-9
Arkansas Public Service Commission
Chart of Accounts
Minimum Filing Requirements
Partially Projected Test Year Ended
Entergy Arkansas, Inc.
March 31, 2015
Docket No. 15-015-U
(1)
LN
(2)
Account
781
302
Franchises and Consents
This account shall include amounts paid to the federal
government, to a state or to a political subdivision thereof in
consideration for franchises, consents, water power licenses, or
certificates, running in perpetuity or for a specified term of more
than one year, together with necessary and reasonable expenses
incident to procuring such franchises, consents, water power
licenses, or certificates of permission and approval, including
expenses of organizing and merging separate corporations, where
statutes require, solely for the purpose of acquiring franchises.
782
303
Miscellaneous Intangible Plant
This account shall include the cost of patent rights, licenses,
privileges, and other intangible property necessary or valuable in
the conduct of utility operations and not specifically chargeable to
any other account.
783
(3)
Account Title
(4)
Account Description
Steam Production Plant
784
310.1
Land
785
311
Structures and Improvements
786
312
Boiler Plant Equipment
787
314
Turbogenerator Units
788
315
Accessory Electric Equipment
789
316
Misc. Power Plant Equipment
790
317
Asset Retirement Costs
791
This account shall include the cost of land and land rights used in
connection with steam-power generation. (See USOA electric
plant instruction 7.)
This account shall include the cost in place of structures and
improvements used in connection with steam-power generation.
(See USOA electric plant instruction 8.)
This account shall include the cost installed of furnaces, boilers,
coal and ash handling and coal preparing equipment, steam and
feed water piping, boiler apparatus and accessories used in the
production of steam, mercury, or other vapor, to be used primarily
for generating electricity.
This account shall include the cost installed of main turbine-driven
units and accessory equipment used in generating electricity by
steam.
This account shall include the cost installed of auxiliary generating
apparatus, conversion equipment, and equipment used primarily
in connection with the control and switching of electric energy
produced by steam power, and the protection of electric circuits
and equipment, except electric motors used to drive equipment
included in other accounts. Such motors shall be included in the
account in which the equipment with which they are associated is
included.
This account shall include the cost installed of miscellaneous
equipment in and about the steam generating plant devoted to
general station use, and which is not properly includible in any of
the foregoing steam-power production accounts.
This account shall include asset retirement costs on plant included
in the steam production function.
Nuclear Production Plant
792
320.1
Land
793
320.2
Land Rights
794
321
Structures and Improvements
This account shall include the cost of land rights used in
connection with nuclear power generation. (See USOA electric
plant instruction 7.)
This account shall include the cost of land rights used in
connection with nuclear power generation. (See USOA electric
plant instruction 7.)
This account shall include the cost in place of structures and
improvements used and useful in connection with nuclear power
generation. (See USOA electric plant instruction 8.)
E-9 Page 71 of 99
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41 Schedule E-9
Arkansas Public Service Commission
Chart of Accounts
Minimum Filing Requirements
Partially Projected Test Year Ended
Entergy Arkansas, Inc.
March 31, 2015
Docket No. 15-015-U
(1)
LN
(2)
Account
795
322
Reactor Plant Equipment
This account shall include the installed cost of reactors, reactor
fuel handling and storage equipment, pressurizing equipment,
coolant charging equipment, purification and discharging
equipment, radioactive waste treatment and disposal equipment,
boilers, steam and feed water piping, reactor and boiler apparatus
and accessories and other reactor plant equipment used in the
production of steam to be used primarily for generating electricity,
including auxiliary superheat boilers and associated equipment in
systems which change temperatures or pressure of steam from
the reactor system.
796
323
Turbogenerator Units
797
324
Accessory Electric Equipment
798
325
Misc. Power Plant Equipment
799
326
Asset Retirement Costs
This account shall include the cost installed of main turbine-driven
units and accessory equipment used in generating electricity by
steam.
This account shall include the cost installed of auxiliary generating
apparatus, conversion equipment, and equipment used primarily
in connection with the control and switching of electric energy
produced by nuclear power, and the protection of electric circuits
and equipment, except electric motors used to drive equipment
included in other accounts. Such motors shall be included in the
account in which the equipment with which they are associated is
included.
This account shall include the cost installed of miscellaneous
equipment in and about the nuclear generating plant devoted to
general station use, and which is not properly includible in any of
the foregoing nuclear-power production accounts.
This account shall include asset retirement costs on plant included
in the nuclear production function.
800
(3)
Account Title
(4)
Account Description
Hydraulic Production Plant
801
330.1
Land
802
330.2
Land Rights
803
331.1
Structure and Improvements
804
331.2
Structure/Improve-Conservation
805
331.3
Structure/Improve-Recreation
806
332
Reservoirs, Dams, & Waterways
This account shall include the cost of land used in connection with
hydraulic power generation. (See USOA electric plant instruction
7.) For Major utilities, it shall also include the cost of land and land
rights used in connection with (1) the conservation of fish and
wildlife, and (2) recreation.
This account shall include the cost of land rights used in
connection with hydraulic power generation. (See USOA electric
plant instruction 7.) For Major utilities, it shall also include the cost
of land and land rights used in connection with (1) the
conservation of fish and wildlife, and (2) recreation.
This account shall include the cost in place of structures and
improvements used in connection with hydraulic power
generation. (See USOA electric plant instruction 8.) For Major
utilities, it shall also include the cost in place of structures and
improvements used in connection with (1) the conservation of fish
and wildlife, and (2) recreation. Separate subaccounts shall be
maintained for each of these.
This account shall include the cost in place of structures and
improvements used in connection with the conservation of fish
and wildlife.
This account shall include the cost in place of structures and
improvements used in connection with recreation.
This account shall include the cost in place of facilities used for
impounding, collecting, storage, diversion, regulation, and delivery
of water used primarily for generating electricity. For Major utilities,
it shall also include the cost in place of facilities used in
connection with (a) the conservation of fish and wildlife, and (b)
recreation. (See USOA electric plant instruction 8C.)
E-9 Page 72 of 99
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41 Schedule E-9
Arkansas Public Service Commission
Chart of Accounts
Minimum Filing Requirements
Partially Projected Test Year Ended
Entergy Arkansas, Inc.
March 31, 2015
Docket No. 15-015-U
(1)
LN
(2)
Account
807
333
Waterwheel,Turbine, Generator
This account shall include the cost installed of water wheels and
hydraulic turbines (from connection with penstock or flume to
tailrace) and generators driven thereby devoted to the production
of electricity by water power or for the production of power for
industrial or other purposes, if the equipment used for such
purposes is a part of the hydraulic power plant works.
808
334
Accessory Electric Equipment
809
335.1
Misc. Power Plant Equipment
This account shall include the cost installed of auxiliary generating
apparatus, conversion equipment, and equipment used primarily
in connection with the control and switching of electric energy
produced by hydraulic power and the protection of electric circuits
and equipment, except electric motors used to drive equipment
included in other accounts, such motors being included in the
account in which the equipment with which they are associated is
included.
This account shall include the cost installed of miscellaneous
equipment in and about the hydroelectric generating plant which is
devoted to general station use and is not properly includible in
other hydraulic production accounts. For Major utilities, it shall also
include the cost of equipment used in connection with (a) the
conservation of fish and wildlife, and (b) recreation. Separate
subaccounts shall be maintained for each of these.
810
335.2
Misc Equipment-Conservation
This account shall include the cost of miscellaneous equipment
used in connection with the conservation of fish and wildlife.
811
335.3
Misc Equipment-Recreation
812
337
Asset Retirement Costs
This account shall include the cost of miscellaneous equipment
used in connection with the recreation.
This account shall include asset retirement costs on plant included
in the hydraulic production function.
813
(3)
Account Title
(4)
Account Description
Other Production Plant
814
340.1
Land
This account shall include the cost of land used in connection with
other power generation. (See USOA electric plant instruction 7.)
815
341
Structures and Improvements
816
342
Fuelholders, Producers, Access
817
343
Prime Movers
818
344
Generators
819
345
Accessory Electric Equipment
820
346
Misc. Power Plant Equipment
This account shall include the cost in place of structures and
improvements used in connection with other power generation.
(See USOA electric plant instruction 8.)
This account shall include the cost installed of fuel handling and
storage equipment used between the point of fuel delivery to the
station and the intake pipe through which fuel is directly drawn to
the engine, also the cost of gas producers and accessories
devoted to the production of gas for use in prime movers driving
main electric generators.
This account shall include the cost installed of Diesel or other
prime movers devoted to the generation of electric energy,
together with their auxiliaries.
This account shall include the cost installed of Diesel or other
power driven main generators.
This account shall include the cost installed of auxiliary generating
apparatus, conversion equipment, and equipment used primarily
in connection with the control and switching of electric energy
produced in other power generating stations, and the protection of
electric circuits and equipment, except electric motors used to
drive equipment included in other accounts. Such motors shall be
included in the account in which the equipment with which it is
associated is included.
This account shall include the cost installed of miscellaneous
equipment in and about the other power generating plant, devoted
to general station use, and not properly includible in any of the
foregoing other power production accounts.
E-9 Page 73 of 99
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41 Schedule E-9
Arkansas Public Service Commission
Chart of Accounts
Minimum Filing Requirements
Partially Projected Test Year Ended
Entergy Arkansas, Inc.
March 31, 2015
Docket No. 15-015-U
(1)
LN
(2)
Account
821
347
822
(3)
Account Title
Asset Retirement Costs
(4)
Account Description
This account shall include asset retirement costs on plant included
in the other production function.
Transmission Plant
823
350.1
Land
This account shall include the cost of land used in connection with
transmission operations. (See USOA electric plant instruction 7.)
824
350.2
Land Rights
825
352
Structure and Improvements
826
353
Station Equipment
827
354
Towers and Fixtures
828
355
Poles and Fixtures
829
356
Overhead Conductors & Devices
830
357
Underground Conduit
831
358
Underground Conductor,Devices
832
359
Roads and Trails
This account shall include the cost of land rights used in
connection with transmission operations. (See USOA electric plant
instruction 7.)
This account shall include the cost in place of structures and
improvements used in connection with transmission operations.
(See USOA electric plant instruction 8.)
This account shall include the cost installed of transforming,
conversion, and switching equipment used for the purpose of
changing the characteristics of electricity in connection with its
transmission or for controlling transmission circuits.
This account shall include the cost installed of towers and
appurtenant fixtures used for supporting overhead transmission
conductors.
This account shall include the cost installed of transmission line
poles, wood, steel, concrete, or other material, together with
appurtenant fixtures used for supporting overhead transmission
conductors.
This account shall include the cost installed of overhead
conductors and devices used for transmission purposes.
This account shall include the cost installed of underground
conduit and tunnels used for housing transmission cables or
wires. (See USOA electric plant instruction 14.)
This account shall include the cost installed of underground
conductors and devices used for transmission purposes.
This account shall include the cost of roads, trails, and bridges
used primarily as transmission facilities.
833
Distribution Plant
834
360.1
Land
This account shall include the cost of land used in connection with
distribution operations. (See USOA electric plant instruction 7.)
835
360.2
Land Rights
836
361
Structures and Improvements
837
362
Station Equipment
838
364
Poles, Towers, and Fixtures
839
365
Overhead Conductors & Devices
840
366
Underground Conduit
This account shall include the cost of land rights used in
connection with distribution operations. (See USOA electric plant
instruction 7.)
This account shall include the cost in place of structures and
improvements used in connection with distribution operations.
(See USOA electric plant instruction 8.)
This account shall include the cost installed of station equipment,
including transformer banks, etc., which are used for the purpose
of changing the characteristics of electricity in connection with its
distribution.
This account shall include the cost installed of poles, towers, and
appurtenant fixtures used for supporting overhead distribution
conductors and service wires.
This account shall include the cost installed of overhead
conductors and devices used for distribution purposes.
This account shall include the cost installed of underground
conduit and tunnels used for housing distribution cables or wires.
841
367
Underground Conductor, Devices
This account shall include the cost installed of underground
conductors and devices used for distribution purposes.
E-9 Page 74 of 99
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41 Schedule E-9
Arkansas Public Service Commission
Chart of Accounts
Minimum Filing Requirements
Partially Projected Test Year Ended
Entergy Arkansas, Inc.
March 31, 2015
Docket No. 15-015-U
(1)
LN
(2)
Account
842
368
Line Transformers
This account shall include the cost installed of overhead and
underground distribution line transformers and poletype and
underground voltage regulators owned by the utility, for use in
transforming electricity to the voltage at which it is to be used by
the customer, whether actually in service or held in reserve.
843
369.1
Services-Overhead
844
369.2
Services-Underground
This account shall include the cost installed of overhead and
underground conductors leading from a point where wires leave
the last pole of the overhead system or the distribution box or
manhole, or the top of the pole of the distribution line, to the point
of connection with the customer's outlet or wiring.
This account shall include the cost installed of overhead and
underground conductors leading from a point where wires leave
the last pole of the overhead system or the distribution box or
manhole, or the top of the pole of the distribution line, to the point
of connection with the customer's outlet or wiring. Conduit used
for underground service conductors shall be included herein.
845
370
Meters
846
371
Installations On Cust Premises
847
371.1
Install-Non-Roadway Lighting
This account shall include the cost installed of equipment on the
customer's side of a meter when the utility incurs such cost and
when the utility retains title to and assumes full responsibility for
maintenance and replacement of such property.
848
373.1
Street Light & Signal Systems
849
373.2
Street Lighting - Non Roadway
This account shall include the cost installed of equipment used
wholly for public street and highway lighting or traffic, fire alarm,
police, and other signal systems.
This account shall include the cost installed of equipment for
security lighting.
850
(3)
Account Title
(4)
Account Description
This account shall include the cost installed of meters or devices
and appurtenances thereto, for use in measuring the electricity
delivered to its users, whether actually in service or held in
reserve.
This account shall include the cost installed of equipment on the
customer's side of a meter when the utility incurs such cost and
when the utility retains title to and assumes full responsibility for
maintenance and replacement of such property. This account
shall not include leased equipment, for which see account 372,
Leased Property on Customers' Premises.
Regional Transmission And Market Operation Plant
851
382
Computer Hardware
852
383
Computer Software
853
This account shall include the cost of computer hardware and
miscellaneous information technology equipment to provide
scheduling, system control and dispatching, system planning,
standards development, market monitoring, and market
administration activities.
This account shall include the cost of off-the-shelf and in-house
developed software purchased and used to provide scheduling,
system control and dispatching, system planning, standards
development, market monitoring, and market administration
activities.
General Plant
854
389.1
Land
855
390
Structures and Improvements
This account shall include the cost of land used for utility
purposes, the cost of which is not properly includible in other land
accounts. (See USOA electric plant instruction 7.)
This account shall include the cost in place of structures and
improvements used for utility purposes, the cost of which is not
properly includible in other structures and improvements accounts
(See USOA electric plant instruction 8.)
E-9 Page 75 of 99
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41 Schedule E-9
Arkansas Public Service Commission
Chart of Accounts
Minimum Filing Requirements
Partially Projected Test Year Ended
Entergy Arkansas, Inc.
March 31, 2015
Docket No. 15-015-U
(1)
LN
(2)
Account
856
391.1
Office Furniture and Equipment
857
391.2
Computer Equipment
858
391.3
Data Handling Equipment
859
392
Transportation Equipment
860
393
Stores Equipment
861
394
Tools, Shop & Garage Equipment
862
395
Laboratory Equipment
863
396
Power Operated Equipment
864
397.1
Communication Equipment
865
397.2
Microwave & Fiber Optic Equip
866
398
Miscellaneous Equipment
867
399
Other Tangible Property
868
(3)
Account Title
(4)
Account Description
This account shall include the cost of office furniture and
equipment owned by the utility and devoted to utility service, and
not permanently attached to buildings, except the cost of such
furniture and equipment which the utility elects to assign to other
plant accounts on a functional basis.
This account shall include the cost of computer equipment owned
by the utility and devoted to utility service.
This account shall include the cost of data handling equipment
owned by the utility and devoted to utility service.
This account shall include the cost of transportation vehicles used
for utility purposes.
This account shall include the cost of equipment used for the
receiving, shipping, handling, and storage of materials and
supplies.
This account shall include the cost of tools, implements, and
equipment used in construction, repair work, general shops and
garages and not specifically provided for or includible in other
accounts.
This account shall include the cost installed of laboratory
equipment used for general laboratory purposes and not
specifically provided for or includible in other departmental or
functional plant accounts.
This account shall include the cost of power operated equipment
used in construction or repair work exclusive of equipment
includible in other accounts. Include, also, the tools and
accessories acquired for use with such equipment and the vehicle
on which such equipment is mounted.
This account shall include the cost installed of telephone,
telegraph, and wireless communication equipment for general use
in connection with utility operations.
This account shall include the cost installed of microwave and
fiber optic communication equipment for general use in
connection with utility operations.
This account shall include the cost of equipment, apparatus, etc.,
used in the utility operations, which is not includible in any other
plant account.
This account shall include the cost of tangible utility plant not
provided for elsewhere.
Income Accounts
869
4030AM
Depreciation Expense
870
4030IS
Depr Exp Contra PIS EAI Securi
871
403110
DEPR EXPENSE - ARO ASSETS
872
403115
Dep Exp-Remov-Fos Steam Contra
873
403116
Deprec Exp ARO Asset-Fossil
874
403117
Dep Exp-Removal-Hydro Contra
This account shall include the amount of depreciation expense for
all classes of depreciable electric plant in service except such
depreciation expense as is chargeable to clearing accounts or to
account 416, Costs and Expenses of Merchandising, Jobbing and
Contract Work.
This account contains the depreciation expense for storm
restoration costs and the associated accumulated reserve account
is 1080IS.
To record the depreciation expense on the asset retirement
obligations for asbestos removal at nuclear steam generating
units.
This account contains the depreciation expense related to the
COR component and the associated accumulated reserve
account is 108260.
This account contains the depreciation expense for asset
retirement costs and the associated accumulated reserve account
is 108110.
This account contains the depreciation expense related to the
COR component and the associated accumulated reserve
account is 108261.
E-9 Page 76 of 99
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41 Schedule E-9
Arkansas Public Service Commission
Chart of Accounts
Minimum Filing Requirements
Partially Projected Test Year Ended
Entergy Arkansas, Inc.
March 31, 2015
Docket No. 15-015-U
(1)
LN
(2)
Account
875
403118
Deprec Exp-ARO Asset-Hydro
876
403119
Dep Exp-Remove-Oth Gen Contra
877
403120
Deprec Exp-ARO Asset-Other Gen
878
4031AM
Deprec Exp billed from Serv Co
879
4040AM
Amort Limited Term Electrc Plt
880
4041AM
Amort Exp billed from Serv Co
881
406000
Amort - Hot Spring Plant
882
407303
Gg1 Costs-Over/Under Recvry-A
883
407312
Ises Synchronization Adjustmnt
884
407342
Reg DR - Fed. Lit. Consult Fee
885
407343
Reg Debit-Energy Efficiency
886
407344
Reg Debit-EAI 30-Year Retail
887
407345
Reg DR-Extraord Storm Restor
888
407348
REGULATORY DEBITS
889
407350
Regulatory Debits - Aro
890
407356
Reg Debit - Act 310
891
892
407357
407363
Reg Debit - EAI Study
Regulatory Debits-MISO Rider
893
407364
Reg Dr - EAI Storm Interest
(3)
Account Title
(4)
Account Description
This account contains the depreciation expense for asset
retirement costs and the associated accumulated reserve account
is 108111.
This account contains the depreciation expense related to the
COR component and the associated accumulated reserve
account is 108262.
This account contains the depreciation expense for asset
retirement costs and the associated accumulated reserve account
is 108112.
This account contains the service company depreciation billing
allocations.
This account includes amortization charges applicable to amounts
included in the electric plant accounts for limited-term franchises,
licenses, patent rights, limited-term interests in land, and
expenditures on leased property where the service life of the
improvements is terminable by action of the lease. The charges to
this account shall be such as to distribute the book cost of each
investment as evenly as may be over the period of its benefit to
the utility.
This account contains the service company amortization billing
allocations.
This account shall be debited or credited, as the case may be,
with amounts includible in operating expenses, pursuant to
approval or order of the Commission, for the purpose of providing
for the extinguishment of the amount in account 114, Electric
Plant Acquisition Adjustments, pertaining to the Hot Spring CCGT.
This account is used for the Regulatory debit or credit associated
with the over/under collection of the costs recovered through the
Grand Gulf riders at EAI and EMI
This account contains the amortization of ISES Synchronization
ordered by the APSC.
This account will be used to record regulatory debits/credits for
Federal Litigation Consulting fee.
This account will be used to record regulatory debits/credits for
Energy Efficiency.
This account shall be used to record other than temporary
impairments on decommissioning trust investments.
This account will be used to record regulatory debit/credit for
extraordinary storm restoration cost.
This account shall be debited, when appropriate, with the
amounts credited to Account 254, Other Regulatory Liabilities, to
record regulatory liabilities imposed on the utility by the
ratemaking actioins of regulatory agencies. This account shall
also be debited, when appropriate, with the amounts credited to
Account 182.3, Other Regulatory Assets, concurrent with the
recovery of such amounts in rates.
This account will be used to record regulatory debits for asset
retirement obligations.
This account will be used to accumulate Act 310 surcharge
revenues.
This account will be used to accumulate EAI study revenues.
Reg debit for over recovery of costs associated with the MISO
Rider.
To amortize interest previously accrued/recorded on under
recovered storm costs as it's being recovered in base rates per
APSC Order No. 21 in Docket 13-028-U.
E-9 Page 77 of 99
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41 Schedule E-9
Arkansas Public Service Commission
Chart of Accounts
Minimum Filing Requirements
Partially Projected Test Year Ended
Entergy Arkansas, Inc.
March 31, 2015
Docket No. 15-015-U
(1)
LN
(2)
Account
894
407403
Regulatory Credits
895
407405
Capacity Acquisition Rider Def
896
407410
Regulatory Credit - Aro
897
407425
Reg Credit-ARO-Asbestos Remov
898
407463
Regulatory Credit-MISO Rider
899
408100
SALES / USE TAX
900
408105
Taxes Other Than Inc-Util Op
901
408110
Employment Taxes
902
408122
Excise Tax - State
903
408123
EXCISE TAX - FEDERAL
904
408142
Ad Valorem
905
408152
Franchise Tax - State
906
408154
Franchise Tax - Local
907
408155
FRANCHISE TAX - MS
(3)
Account Title
(4)
Account Description
This account shall be credited, when appropriate, with the
amounts debited to Account 182.3, Other Regulatory Assets, to
establish regulatory assets. This account shall also be credited,
when appropriate, with the amounts debited to Account 254,
Other Regulatory Liabilities, concurrent with the return of such
amounts to customers through rates.
This account will be used to record the deferral related to PostAcquisition EAI Capacity Rider.
This account will be used to record regulatory credits for asset
retirement obligations.
To record the credit from the difference between asbestos
removal cost as determined under prov FIN 47 and depreciation
exp in recoverable depreciation exp for ratemaking.
Regulatory credit for under recovery of costs associated with
MISO Rider.
This account shall include those taxes other than income taxes
which relate to utility operating income. This account shall be
maintained so as to allow ready identification of the various
classes of taxes relating to Utility Operating Income (by
department), Utility Plant Leased to Others and Other Utility
Operating Income.
This account shall include the amounts represents taxes other
than income taxes included in the reserve of taxes other than
income taxes.
This account shall be used to record employment taxes, such as
employer FICA, federal and state unemployemnt taxes.
This account shall include the amounts of state excise taxes and it
shall be charged in each accounting period with the amounts of
taxes which are applicable thereto, with concurrent credits to
account 236, Taxes Accrued or account 165, Prepayments as
appropriate.
Account to record Federal Excise Tax expense that applies to the
person who pays insurance premiums on policies issued by
foreign insurers. Also, this account is used to record Federal
Highway Use Tax expense that applies to all highway motor
vehicles having a gross weight of 55,000 pounds or more.
This account shall include the amounts of ad valorem taxes and it
shall be charged in each accounting period with the amounts of
taxes which are applicable thereto, with concurrent credits to
account 236, Taxes Accrued or account 165, Prepayments as
appropriate.
This account shall include the amounts of state franchise taxes
and it shall be charged in each accounting period with the
amounts of taxes which are applicable thereto, with concurrent
credits to account 236, Taxes Accrued or account 165,
Prepayments as appropriate.
This account shall include the amounts of city franchise taxes and
it shall be charged in each accounting period with the amounts of
taxes which are applicable thereto, with concurrent credits to
account 236, Taxes Accrued or account 165, Prepayments as
appropriate.
This account shall include the amounts of state (MS) franchise
taxes and it shall be charged in each accounting period with the
amounts of taxes which are applicable thereto, with concurrent
credits to account 236, Taxes Accrued or account 165,
Prepayments as appropriate.
E-9 Page 78 of 99
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41 Schedule E-9
Arkansas Public Service Commission
Chart of Accounts
Minimum Filing Requirements
Partially Projected Test Year Ended
Entergy Arkansas, Inc.
March 31, 2015
Docket No. 15-015-U
(1)
LN
(2)
Account
908
408156
Franchise Tax - Arkansas
909
408157
Franchise Tax - Missouri
910
408164
Gross Receipts & Sales Tax
911
408165
City Occupation Tax
912
408166
Privilege Tax
913
408172
Regulatory Commission - State
914
915
408199
408202
Payroll Tax Loading
Taxes Other Than Inc- O I & D
916
409112
Income Taxes-Util Op Inc - Fed
917
409114
Income Taxes-Util Op Inc-State
918
409148
Uncertain Income Taxes-Federal
919
409149
Uncertain Income Taxes - State
920
409210
Income Taxes-O I & D - Federal
921
409220
Income Taxes - O I & D - State
922
410101
Prov Defer Inc Taxes-Util-Fed
923
410120
Prov Def Inc Tax-Util Op-State
924
411105
Accretion Expense - Aro
925
411107
Accretion Exp-ARO Asset-Fossil
926
411108
Accretion Exp-ARO Asset-Hydro
927
411109
Accret Exp-ARO Asset-Other Gen
928
411110
Prov Def Inc Tax-Cr-Op Inc-Fed
(3)
Account Title
(4)
Account Description
This account shall include the amounts of state franchise taxes
and it shall be charged in each accounting period with the
amounts of taxes which are applicable thereto, with concurrent
credits to account 236, Taxes Accrued or account 165,
Prepayments as appropriate.
This account shall include the amounts of state franchise taxes
and it shall be charged in each accounting period with the
amounts of taxes which are applicable thereto, with concurrent
credits to account 236, Taxes Accrued or account 165,
Prepayments as appropriate.
This account includes the sales tax on power used by Entergy
Mississippi.
This account shall include the amounts of city occupation taxes
and it shall be charged in each accounting period with the
amounts of taxes which are applicable thereto, with concurrent
credits to account 236, Taxes Accrued or account 165,
Prepayments as appropriate.
This account includes Tennessee Gross Receipts Taxes based on
Tennessee Revenues.
This account shall include the amounts of regulatory commission
fees and it shall be charged in each accounting period with the
amounts of taxes which are applicable thereto, with concurrent
credits to account 236, Taxes Accrued or account 165,
Prepayments as appropriate.
This account shall include Payroll Tax Loading.
This account shall include those taxes other than income taxes
which relate to Other Income and Deductions.
This account shall include the amount of federal income taxes
which relate to utility operating income.
This account shall include the amount of state income taxes which
relate to utility operating income.
This account shall include the amount of federal income taxes
which relate to the FIN48 liability adjustments.
This account shall include the amount of state income taxes which
relate to the FIN48 liability adjustments.
This account shall include the amount of federal income taxes
which relate to Other Income and Deductions.
This account shall include the amount of state income taxes which
relate to Other Income and Deductions.
This account shall include the amounts of those deferrals of
federal taxes and allocations of federal deferred taxes which relate
to Utility Operating Income.
This account shall include the amounts of those deferrals of state
taxes and allocations of state deferred taxes which relate to Utility
Operating Income.
This account shall include the amounts of those allocations of
deferred taxes and deferrals of taxes, credit, which relate to
accretion expense ARO.
This account shall include the amounts of those allocations of
deferred taxes and deferrals of taxes, credit, which relate to
accretion expense of the ARO asset for fossil plants.
This account shall include the amounts of those allocations of
deferred taxes and deferrals of taxes, credit, which relate to
accretion expense of the ARO asset for hydro plants.
This account shall include the amounts of those allocations of
deferred taxes and deferrals of taxes, credit, which relate to
accretion expense of the ARO asset for other generation.
This account shall include the amounts of those allocations of
federal deferred taxes and deferrals of federal taxes, credit, which
relate to Utility Operating Income.
E-9 Page 79 of 99
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41 Schedule E-9
Arkansas Public Service Commission
Chart of Accounts
Minimum Filing Requirements
Partially Projected Test Year Ended
Entergy Arkansas, Inc.
March 31, 2015
Docket No. 15-015-U
(1)
LN
(2)
Account
(3)
Account Title
929
411120
Prov Def Inc Tax-Cr-Op Inc-Sta
930
411430
Itc Amortization
931
4117AM
LOSS - DISPOSITION OF UTIL PLT
(4)
Account Description
This account shall include the amounts of those allocations of
state deferred taxes and deferrals of state taxes, credit, which
relate to Utility Operating Income.
This account shall include the amount of those investment tax
credit adjustments related to property used in Utility Operations.
A. This account shall include, as approved by the Commission,
amounts relating to losses from the disposition of future use utility
plant including amounts which were previously recorded in and
transferred from account 105, Electric Plant Held for Future Use,
under the provisions of paragraphs B, C, and D thereof. Income
taxes relating to losses, recorded in this account shall be recorded
in account 409.1, Income Taxes, Utility Operating Income.
B. The utility shall record in this account losses resulting from the
settlement of asset retirement obligations related to utility plant in
accordance with the accounting prescribed in General Instruction
25.
932
411800
Gain From Dispostn Of Allownce
933
4171AM
Expenses - Non Utility Oper
934
418000
NONOPERATING RENTAL INCOME
This account shall be credited with the gain on the sale,
exchange, or other disposition of allowances in accordance with
paragraph (H) of USOA General Instruction No. 21.
This account includes revenues and expenses applicable to
operations which are nonutility in character but nevertheless
constitute a distinct operating activity of the enterprise as a whole.
A. This account shall include all rent revenues and related
expenses of land, buildings, or other property included in account
121, Nonutility Property, which is not used in operations covered
by account 417 or 417.1. B. The expenses shall include all
elements of costs incurred in the ownership and rental of property
and the accounts shall be maintained so as to permit ready
summarization as follows: Operation, maintenance, rents,
depreciation, amortization.
Note: Related taxes shall be recorded in account 408.2. Taxes
Other Than Income Taxes, Other Income and Deductions, or
account 409.2, Income Taxes, Other Income and Deductions, as
appropriate.
935
418100
Equity Earnings Subs Cos
936
418104
Equity in earnings-Arklahoma
937
419000
Interest & Dividend Income
938
419003
Decomm - realized gains/losses
This account shall include the utility's equity in the earnings or
losses of subsidiary companies for the year.
This account is required for income statement presentation
reasons. It will be used by EAI to record its equity in earnings from
Arklahoma that was previously recorded in the generic 418100
account. The account previously used (the 418100) rolls into the
competitive business revenue line item on the income statement
and we want to get the Arklahoma entry to roll elsewhere (in the
equity in earnings of unconsolidated affiliates line).
This account shall include interest revenues on securities, loans,
notes, advances, special deposits, tax refunds and all other
interest-bearing assets, and dividends on stocks of other
companies, whether the securities on which the interest and
dividends are received are carried as investments or included in
sinking or other special fund accounts.
To record in a separate sub-account the decommissioning trust
realized gains/losses (to facilitate cash flow presentation).
E-9 Page 80 of 99
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41 Schedule E-9
Arkansas Public Service Commission
Chart of Accounts
Minimum Filing Requirements
Partially Projected Test Year Ended
Entergy Arkansas, Inc.
March 31, 2015
Docket No. 15-015-U
(1)
LN
(2)
Account
939
419004
Decomm - Trust Earnings
940
419011
Affiliated Interest Income
941
419012
Interest Income - Sfi
942
419100
Afudc - Other Funds
943
421000
Misc Nonoperating Income
944
4211AM
Gain On Disposition Of Proprty
945
421200
LOSS ON DISPOSITION OF PROP
946
4212AM
Loss On Disposition Of Proprty
947
421340
Royalty Income
948
426100
Donations
949
426300
Penalties
950
426310
Penalties - Income Tax
951
426400
Exp-Civic,Political & Rel Act
952
426500
Other Deductions
This account shall include other miscellaneous expenses which
are nonoperating in nature, but which are properly deductible
before determining total income before interest charges.
953
4265AD
AFDC Dr Cntra APSC Ord 09-84-U
This account will record the contra AFUDC Debt entries needed to
reduce the FERC formula calculated AFUDC rate to the lower
5.04% capped rate per APSC Docket 09-84-U order. The offset
will be to other deferred credits. Only the Accounting Department
should charge this account and the related other deferred credit
account.
(3)
Account Title
(4)
Account Description
To record in a separate sub-account the decommissioning trust
fund earnings.
This account is used to facilitate use of Affiliate field in PeopleSoft.
To record in a separate sub-account the interest income on
Entergy Arkansas' note receivable investment in its subsidiary
System Fuels.
This account shall include concurrent credits for allowance for
other funds used during construction, not to exceed amounts
computed in accordance with the formula prescribed in USOA
Electric Plant Instruction 3(17).
This account shall include all revenue and expense items except
taxes properly includible in the income account and not provided
for elsewhere.
This account shall be credited with the gain on the sale,
conveyance, exchange, or transfer of utility or other property to
another.
This account shall be charged with the loss on the sale,
conveyance, exchange or transfer of utility or other property to
another. Amounts relating to losses on land and land rights held
for future use recorded in account 105, Electric Plant Held for
Future Use will be accounted for as prescribed in paragraphs B,
C, and D thereof. (See electric plant instructions 5F, 7E, and 10E.)
The reduction in income taxes relating to losses recorded in this
account shall be recorded in account 409.2, Income Taxes, Other
Income and Deductions.
This account shall be charged with the loss on the sale,
conveyance, exchange or transfer of utility or other property to
another.
This account records the revenues associated with managing oil
and gas leases on Entergy owned property to outside parties.
This account shall include all payments or donations for
charitable, social or community welfare purposes.
This account shall include payments by the company for penalties
or fines for violation of any regulatory statutes by the company or
its officials.
This account shall include payments by the company for penalties
or fines for violation of any tax statutes.
This account shall include expenditures for the purpose of
influencing public opinion with respect to the election or
appointment of public officials, referenda, legislation, or
ordinances (either with respect to the possible adoption of new
referenda, legislation or ordinances or repeal or modification of
existing referenda, legislation or ordinances) or approval,
modification, or revocation of franchises; or for the purpose of
influencing the decisions of public officials, but shall not include
such expenditures which are directly related to appearances
before regulatory or other governmental bodies in connection with
the reporting utility's existing or proposed operations.
E-9 Page 81 of 99
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41 Schedule E-9
Arkansas Public Service Commission
Chart of Accounts
Minimum Filing Requirements
Partially Projected Test Year Ended
Entergy Arkansas, Inc.
March 31, 2015
Docket No. 15-015-U
(1)
LN
(2)
Account
954
4265AE
AFDC Eqty Cntr APSC Or 09-84-U
955
4265AM
Disallowed EAI Amort Exp
956
4265DP
Disallowed EAI Depr Exp
Per APSC Docket 09-84-U order, certain Incentive Costs were
disallowed along with the associated AFUDC and Capital
Suspense this special account will track the Other Deduction
Depreciation Expenses related to the Other deferred liabilities in
accounts 253101 and 253106. Only the Accounting Department
should charge this other defferred credit account.
957
4265OT
Disallowed EAI Other Exp
958
4265TX
Disalow PR Tx APSC Ord 09-84-U
959
427000
Interest On Long Term Debt
960
427100
First Mortgage Bonds
961
427198
Doe Spent Nf Disposal Cost
962
428000
Amort-Debt Discount & Expense
963
428100
Amort Of Loss On Reacq Debt
964
430000
Interco Int Exp-Unrelated
Per APSC Docket 09-84-U order, certain Incentive Costs were
disallowed along with the associated AFUDC and Capital
Suspense this special account will track the Other Deduction
Expenses related to the Other deferred liabilities in accounts
253101, 253106 and 253107. Only the Accounting Department
should charge this other defferred credit account.
This account will record the contra entries to expense the
capitalized payroll taxes related to the 18.04% disallowed
incentive compensation. The offset will be to other deferred
credits. Only the Accounting Department should charge this
account and the other deferred credit account.
This account shall include the amount of interest on outstanding
long-term debt issued or assumed by the utility, the liability for
which is included in account 221, Bonds, or account 224, Other
Long-Term Debt.
This account shall include the amount of interest on outstanding
long-term debt issued or assumed by the utility, the liability for
which is included in account 221, Bonds.
This account shall include the amount of interest on the DOE
obligation, the liability for which is included in account 224.
This account shall include the amortization of unamortized debt
discount and expense on outstanding long-term debt. Amounts
charged to this account shall be credited concurrently to accounts
181, Unamortized Debt Expense, and 226, Unamortized Discount
on Long-Term Debt—Debit.
This account shall include the amortization of the losses on
reacquisition of debt. Amounts charged to this account shall be
credited concurrently to account 189, Unamortized Loss on
Reacquired Debt.
This account shall include the interest accrued on amounts
included in account 223, Advances from Associated Companies,
and on all other obligations to associated companies.
965
431000
Other Interest Expense
966
431003
Tax Deficiencies
967
431006
Bank Loans - Interest Exp.
968
431191
Accrued Interest on UTPs
(3)
Account Title
(4)
Account Description
This account will record the contra AFUDC Equiy entries needed
to reduce the FERC formula calculated AFUDC rate to the lower
5.04% capped rate per APSC Docket 09-84-U order. The offset
will be to other deferred credits. Only the Accounting Department
should charge this account and the related other deferred credit
account.
Per APSC Docket 09-84-U order, certain Incentive Costs were
disallowed along with the associated AFUDC and Capital
Suspense this special account will track the Other Deduction
Amortization Expenses related to the Other deferred liabilities in
accounts 253101 and 253106. Only the Accounting Department
should charge this other defferred credit account.
This account shall include all interest charges not provided for
elsewhere.
This account shall include all interest charges related to tax
deficiencies.
This account shall include all interest charges related to various
bank lines of credit.
To capture the Interest Expense in separate account according to
FERC order for proper FIN48 presentation purposes.
E-9 Page 82 of 99
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41 Schedule E-9
Arkansas Public Service Commission
Chart of Accounts
Minimum Filing Requirements
Partially Projected Test Year Ended
Entergy Arkansas, Inc.
March 31, 2015
Docket No. 15-015-U
(1)
LN
(2)
Account
(3)
Account Title
969
431194
Interest Pymts on UTPs - State
970
432000
Afudc -Borrowed Funds - Cr.
971
437000
Dividends Dec-Preferred Stock
972
438000
Dividends Declared-Common Stk
973
440000
Residential Sales
974
442100
Commercial Sales
975
442200
Industrial Sales
976
444000
Public Street & Hwy Lighting
977
445000
Other Sales To Pub. Authorit
978
447001
Sales For Resale Assoc Co
979
447002
Sales For Resale Non Assoc Co
980
447003
TRANSMISSION SERVICES OTHER
981
447005
Imputed Transmission Revenue
982
447115
Resource Plan Rev - Affiliated
983
447116
Mississippi Power & Light Co
984
447117
Entergy Power Inc.
985
447305
Conway Corporation
986
447307
Jonesboro City Water & Light
987
447309
City Of Osceola
988
447314
City Of West Memphis
989
447404
Arkansas Electric Coop Corp
990
447501
Union Electric Company
991
447515
Grand Gulf Retained Shares Rp
992
447600
East Texas Elec Coop, Inc.
(4)
Account Description
To record actual state interest payments on resolved uncertain tax
positions.
This account shall include concurrent credits for allowance for
borrowed funds used during construction, not to exceed amounts
computed in accordance with the formula prescribed in USOA
Electric Plant Instruction 3(17).
This account shall include amounts declared payable out of
retained earnings as dividends on actually outstanding preferred
or prior lien capital stock issued by the utility.
This account shall include amounts declared payable out of
retained earnings as dividends on actually outstanding common
capital stock issued by the utility.
This account shall include the net billing for electricity supplied for
residential or domestic purposes.
This account shall include the net billing for electricity supplied to
customers for commercial purposes.
This account shall include the net billing for electricity supplied to
customers for industrial purposes.
This account shall include the net billing for electricity supplied
and services rendered for the purposes of lighting streets,
highways, parks and other public places, or for traffic or other
signal system service, for municipalities or other divisions or
agencies of state or federal governments.
This account shall include the net billing for electricity supplied to
municipalities or divisions or agencies of federal or state
governments, under special contracts or agreements or service
classifications applicable only to public authorities, except such
revenues as are includible in accounts 444 and 447.
Revenues derived from electric operations from associated
Entergy companies.
Revenues derived from electric operations through system sales
to non-associated companies.
Revenue associated with Transmission service for grandfathered
customers.
This account containsTransmission revenue associated with Joint
Account energy sales.
This account contains revenue from sales under the MSS-4 Tariff.
This account contains revenues derived from electric operations
from Mississippi Power & Light Co.
This account contains revenues derived from electric operations
from Entergy Power Inc.
This account contains revenues derived from electric operations
from Conway Corporation.
This account contains revenues derived from electric operations
from Jonesboro City Water & Light.
This account contains revenues derived from electric operations
from City of Osceola.
This account contains revenues derived from electric operations
from City of West Memphis.
This account contains revenues derived from electric operations
from Arkansas Electric Cooperative Corp.
This account contains revenues derived from electric operations
from Union Electric Company.
This account contains revenue from sales of EAI's retained share
of Grand Gulf under the MSS-4 Tariff
This account contains revenues derived from electric operations
from East Texas Electric Cooperative, Inc.
E-9 Page 83 of 99
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41 Schedule E-9
Arkansas Public Service Commission
Chart of Accounts
Minimum Filing Requirements
Partially Projected Test Year Ended
Entergy Arkansas, Inc.
March 31, 2015
Docket No. 15-015-U
(1)
LN
(2)
Account
993
449100
Provision For Rate Refund
This account shall be charged with provisions for the estimated
pretax effects on net income of the portions of amounts being
collected subject to refund which are estimated to be required to
be refunded. Such provisions shall be credited to Account 229,
Accumulated Provision for Rate Refunds.
994
450000
Forfeited Discounts
This account shall include the amount of discounts forfeited or
additional charges imposed because of the failure of customers to
pay their electric bills on or before a specified date.
995
451000
Miscellaneous Service Revenue
996
454000
Rent From Electric Property
997
454100
Pole Attachments
998
456000
Other Electric Revenues
999
456002
DISTRIBUTION SUBSTATION SVC.
This account shall include revenues for all miscellaneous services
and charges billed to customers which are not specifically
provided for in other accounts.
This account shall include rents received for the use by others of
land, buildings, and other property devoted to electric operations
by the utility.
This account includes revenue associated with distribution pole
rental billings for telephone and cable attachments.
This account shall include revenues derived from electric
operations not includible in any other revenue account.
To record the monthlty NITS revenues associated with distribution
substaion service at the Entergy operating companies.
1000
456003
MISO Mkt Sch 11 Wholesale Dist
1001
456010
MISC REV - OUACHITA UPGRADES
1002
4560MS
Third Party Sales of Inventory
1003
456100
Miscellaneous Revenue
1004
456102
Gia Annual Fees
1005
456104
Cwl Transmission Revenue
1006
456107
Network Transmission Revenue
1007
456108
Schdlg Syst Control & Dispatch
1008
456109
Reactive Suppt & Voltage Cntrl
1009
456110
Ar Gross Receipts Tax
1010
456111
Non-Firm Transmission Revenue
1011
456112
Short Term Firm Transm Revenue
1012
456113
Long Term Firm Transm Revenue
(3)
Account Title
(4)
Account Description
This account shall include revenues associated with MISO Market
Schedule 11 for customers billed for wholesale distribution
service.
Revenue recorded at ELL and EMI for the reimbursement of EAI's
share of the Ouachita Supplemental Transmission Upgrades. Use
with activity code OURA.
This account is for the profit or loss on sales of material and
supplies not ordinarily purchased for resale and not handled
through merchandising and jobbing accounts.
This account contains revenue derived from electric operations
that is not includable in any other revenue account.
This account includes fees associated with the Generator
Imbalance Tariff.
This account contains revenue associated with long term firm PTP
service.
This account includes revenue billed under Entergy's Open
Access Transmission Tariff (OATT) - Network Integration
Transmission Service (NITS) Revenue (Attachment H)
This account includes revenue billed under Entergy's Open
Access Transmission Tariff (OATT) - Scheduling, System Control,
and Dispatch Service (Schedule 1 - Ancillary Service)
This account includes revenue billed under Entergy's Open
Access Transmission Tariff (OATT) - Reactive Supply and Voltage
Control Service (Schedule 2 - Ancillary Service)
This account is used to record the Arkansas local sales tax rebate
on business purchases.
This account includes revenue billed under Entergy's Open
Access Transmission Tariff (OATT) - Non-Firm Point-to-Point
(PTP) Transmission Service Revenue (Schedule 8)
This account includes revenue billed under Entergy's Open
Access Transmission Tariff (OATT) - Short Term Firm Point-toPoint (PTP) Transmission Service Revenue (Schedule 7)
This account includes revenue billed under Entergy's Open
Access Transmission Tariff (OATT) - Long Term Firm Point-toPoint (PTP) Transmission Service Revenue (Schedule 7)
E-9 Page 84 of 99
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41 Schedule E-9
Arkansas Public Service Commission
Chart of Accounts
Minimum Filing Requirements
Partially Projected Test Year Ended
Entergy Arkansas, Inc.
March 31, 2015
Docket No. 15-015-U
(1)
LN
(2)
Account
1013
456117
Reg & Freq Response Trans Rev
1014
456118
Spinning Reserve Ptp Tran Rev
1015
456119
Suppl Reserve Ptp Tran Rev
1016
456126
RTO & ICT Start-up Costs Recov
1017
456127
RTO & ICT Operations Costs Rec
1018
456136
MISO Sch 7 Firm PTP - ST
1019
456137
MISO Sch 7 Firm PTP - LT
1020
456138
MISO Sch 8 Non-firm
1021
456139
MISO Sch 9 Network
1022
456141
MISO Sch 41 Stm Securitization
1023
456142
MISO Sch 42 Int/AFUDC Amort
1024
456147
MISO Sch47 Transition Cost Rec
1025
4561A9
AECC MISO Sch 9 Network
1026
4561FR
FFR Transm Revenue
1027
456200
Unbilled Revenue
1028
456410
Trans Equal Charges
1029
456420
Affiliate service fee revenue
1030
457131
MISO Sch 1 Sched/Sys Ctrl/Disp
(3)
Account Title
(4)
Account Description
This account includes revenue billed under Entergy's Open
Access Transmission Tariff (OATT) - Regulation and Frequency
Response Service (Schedule 3 - Ancillary Service)
This account includes revenue billed under Entergy's Open
Access Transmission Tariff (OATT) - Operating Reserve Spinning Reserve Service (Schedule 5 - Ancillary Service)
This account includes revenue billed under Entergy's Open
Access Transmission Tariff (OATT) - Operating Reserve Supplemental Reserve Service (Schedule 6 - Ancillary Service)
This account contains revenue from recovery of start-up costs and
development costs of operating as an ICT for transmission
service.
This account contains the revenue received to recover ongoing
costs of operating as ICT for transmission service.
This account will capture revenues associated with MISO
Schedule 7 for firm point-to-point transmission service - short
term.
This account will capture revenues associated with MISO
Schedule 7 for firm point-to-point transmission service - long term.
This account will capture revenues associated with MISO
Schedule 8 for non-firm point to point transmission service.
This account will capture revenues associated with Network
Integration Transmission Service (NITS).
Schedule 41 provides for the recovery of storm securitization
charges consistent with settlement agreement approved by FERC
in Docket Nos. ER10-984 and ER11-3274. This account shall be
used to record such revenues/charges.
This account shall be used to record the acrued and paid interest
and AFUDC associated with the prepayments for network
upgrades consistent with settlement agreement approved by
FERC in Docket No. ER04-886.
Schedule 47 provides for the recovery of Entergy costs associated
with transition into MISO. Entergy receives these revenues as
MISO collects from Schedule 7, 8 and 9 customers.
This account will capture revenues associated with NITS (Network
Integrated Transmissiion Serviice) specific to AECC.
This account is required for transmission revenues related to
Financial Flowgate Rights (FFRs) in compiance with Attachment T
of the OATT.
This account contains the estimate of the revenues earned for
energy delivered since the latest customer billing. Each month the
estimated unbilled revenue amounts are recorded as revenue and
a receivable, and the prior month’s estimate is reversed. The
difference between the estimate of the unbilled receivable at the
beginning of the period and the end of the period is the amount of
unbilled revenue recognized during the period. The estimate
recorded is primarily based upon an estimate of customer usage
during the unbilled period and the billed price to customers in that
month. This account is used for retail customers.
This account is used to record transmission equalization revenues
resulting from the Entergy System Agreement Service Schedule
MSS-2.
This account is needed to record service fee revenue between
Operating Companies and their respective BondCo subsidiary.
This account shall capture charges for the scheduling and
administration of the movement of power into, out of, through or
within the Local Balancing Authority.
E-9 Page 85 of 99
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41 Schedule E-9
Arkansas Public Service Commission
Chart of Accounts
Minimum Filing Requirements
Partially Projected Test Year Ended
Entergy Arkansas, Inc.
March 31, 2015
Docket No. 15-015-U
(1)
LN
(2)
Account
1031
457132
MISO Sch 2 Reactive
This account shall record charges/revenues related to reactive
supply and voltage control service. Each schedule under MISO is
recorded in a separate Transmission revenue account.
1032
4571A1
AECC MISO Schedule 1
This account shall capture AECC (Arkansas Electric Cooperative
Corp.) revenues/charges for the scheduling and adminstration of
the movement of power into, out of, through or within the Local
Balancing Authority. eclemen FOC0104619 1/29/2014
1033
4571A2
AECC MISO Schedule 2
1034
459000
Company Use
This account shall record AECC (Arkansas Electric Cooperative
Corp.) charges/revenues related to reactive supply and voltage
control services. eclemen
This account contains revenues derived from electric operations
not includible in any other revenue accounts, such as,
compensation for minor or incidental services provided for others,
profit or loss on sale of material and supplies not ordinarily
purchased through merchandising and jobbing accounts,
revenues from transmission of electricity of others over
transmission facilities of the Company, etc.
1035
(3)
Account Title
(4)
Account Description
Steam Power Generation Expenses - Operation
1036
500000
Oper Supervision & Engineerin
1037
501000
Fuel
1038
501100
Fuel - Oil
1039
501203
Fuel-Natural Gas
1040
501301
Fuel - Coal
1041
502000
Steam Expenses
1042
505000
Electric Expenses
1043
506000
Misc Steam Power Expenses
1044
507000
Rents
1045
509100
NOX Emissions Allowance Exp
1046
509101
NOX Seasonal Allowances Exp
This account shall include the cost of labor and expenses incurred
in the general supervision and direction of the operation of steam
power generating stations.
This account shall include the cost of fuel used in the production
of steam for the generation of electricity, including expenses in
unloading fuel from the shipping media and handling thereof up to
the point where the fuel enters the first boiler plant bunker,
hopper, bucket, tank or holder of the boiler-house structure.
This account shall include the cost of fuel oil used in the
production of steam for the generation of electricity.
This account shall include the cost of natural gas fuel used in the
production of steam for the generation of electricity.
This account shall include the cost of coal fuel used in the
production of steam for the generation of electricity.
This account shall include the cost of labor, materials used and
expenses incurred in production of steam for electric generation.
This includes all expenses of handling and preparing fuel
beginning at the point where the fuel enters the first boiler plant
bunker, hopper, tank or holder of the boiler-house structure.
This account shall include the cost of labor, materials used and
expenses incurred in operating prime movers, generators, and
their auxiliary apparatus, switch gear and other electric equipment
to the points where electricity leaves for conversion for
transmission or distribution.
This account shall include the cost of labor, materials used and
expenses incurred which are not specifically provided for or are
not readily assignable to other steam generation operation
expense accounts.
This account shall include all rents of property of others used,
occupied or operated in connection with steam power generation.
(See USOA operating expense instruction 3.)
This account records costs of NOX allowances to meet
requirements of new Clean Air Interstate Rule (CAIR) regulations.
This inventory account is used to record NOX allowances to meet
requirements of new Clean Air Interstate Rule (CAIR) regulations.
E-9 Page 86 of 99
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41 Schedule E-9
Arkansas Public Service Commission
Chart of Accounts
Minimum Filing Requirements
Partially Projected Test Year Ended
Entergy Arkansas, Inc.
March 31, 2015
Docket No. 15-015-U
(1)
LN
(2)
Account
1047
(3)
Account Title
(4)
Account Description
Steam Power Generation Expenses - Maintenance
1048
510000
Maintenance Supr & Engineerin
This account shall include the cost of labor and expenses incurred
in the general supervision and direction of maintenance of steam
generation facilities. Direct field supervision of specific jobs shall
be charged to the appropriate maintenance account. (See USOA
operating expense instruction 1.)
1049
511000
Maintenance Of Structures
This account shall include the cost of labor, materials used and
expenses incurred in the maintenance of steam structures, the
book cost of which is includible in account 311, Structures and
Improvements. (See USOA operating expense instruction 2.)
1050
512000
Maintenance Of Boiler Plant
This account shall include the cost of labor, materials used and
expenses incurred in the maintenance of steam plant, the book
cost of which is includible in account 312, Boiler Plant Equipment.
(See USOA operating expense instruction 2.)
1051
513000
Maintenance Of Electric Plant
This account shall include the cost of labor, materials used and
expenses incurred in the maintenance of electric plant, the book
cost of which is includible in account 313, Engines and EngineDriven Generators, account 314, Turbogenerator Units, and
account 315, Accessory Electric Equipment. (See USOA
operating expense instruction 2 and paragraph B of account 512.)
1052
514000
Maintenance Of Misc Steam Plt
This account shall include the cost of labor, materials used and
expenses incurred in maintenance of miscellaneous steam
generation plant, the book cost of which is includible in account
316, Miscellaneous Power Plant Equipment. (See USOA
operating expense instruction 2.)
1053
1054
Nuclear Power Generation Expenses - Operation
517000
Operation, Supervision & Engr
This account shall include the cost of labor and expenses incurred
in the general supervision and direction of the operation of nuclear
power generating stations. Direct supervision of specific activities,
such as fuel handling, reactor operations, generator operations,
etc., shall be charged to the appropriate account. (See USOA
operating expense instruction 1.)
E-9 Page 87 of 99
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41 Schedule E-9
Arkansas Public Service Commission
Chart of Accounts
Minimum Filing Requirements
Partially Projected Test Year Ended
Entergy Arkansas, Inc.
March 31, 2015
Docket No. 15-015-U
(1)
LN
(2)
Account
1055
518000
Nuclear Fuel Expense
A. This account shall be debited and account 120.5, Accumulated
Provision for Amortization of Nuclear Fuel Assemblies, credited for
the amortization of the net cost of nuclear fuel assemblies used in
the production of energy. The net cost of nuclear fuel assemblies
subject to amortization shall be the cost of nuclear fuel assemblies
plus or less the expected net salvage of uranium, plutonium, and
other byproducts and unburned fuel. The utility shall adopt the
necessary procedures to assure that charges to this account are
distributed according to the thermal energy produced in such
periods. B. This account shall also include the costs involved
when fuel is leased. C. This account shall also include the cost of
other fuels, used for ancillary steam facilities, including superheat.
D. This account shall be debited or credited as appropriate for
significant changes in the amounts estimated as the net salvage
value of uranium, plutonium, and other byproducts contained in
account 157. Nuclear Materials Held for Sale and the amount
realized upon the final disposition of the materials. Significant
declines in the estimated realizable value of items carried in
account 157 may be recognized at the time of market price
declines by charging this account and crediting account 157.
When the declining change occurs while the fuel is recorded in
account 120.3 Nuclear Fuel Assemblies in Reactor, the effect
shall be amortized over the remaining life of the fuel.
1056
518100
Burnup/Amortization
This account records the amortization expense on nuclear fuel.
1057
518200
Doe Spent Fuel
1058
518300
Daily Lease Charges
1059
1060
518400
518500
Other Expenses-R&P, Use & Oil
Nuclear Fuel Dry Casts Storage
1061
519000
Coolants And Water
1062
520000
Steam Expenses
1063
524000
Misc. Nuclear Power Expenses
1064
525000
Rents
This account records the expense associated with the fee owed to
the DOE for a spent fuel storage facility.
This account records the rent expense associated with the saleleaseback of nuclear fuel.
This account records the taxes associated with nuclear fuel.
This account records the amortization of the costs of dry fuel
storage casks for spent nuclear fuel.
This account shall include the cost of labor, materials used and
expenses incurred for heat transfer materials and water used for
steam and cooling purposes.
This account shall include the cost of labor, materials used and
expenses incurred in production of steam through nuclear
processes, and similar expenses for operation of any auxiliary
superheat facilities
This account shall include the cost of labor, materials used and
expenses incurred which are not specifically provided for or are
not readily assignable to other nuclear generation operation
accounts.
This account shall include all rents of property of others used,
occupied or operated in connection with nuclear generation. (See
USOA operating expense instruction 3.)
1065
1066
(3)
Account Title
(4)
Account Description
Nuclear Power Generation Expenses - Maintenance
528000
Maint Supervision & Engr
This account shall include the cost of labor and expenses incurred
in the general supervision and direction of maintenance of nuclear
generation facilities. Direct field supervision of specific jobs shall
be charged to the appropriate maintenance account. (See USOA
operating expense instruction 1.)
E-9 Page 88 of 99
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41 Schedule E-9
Arkansas Public Service Commission
Chart of Accounts
Minimum Filing Requirements
Partially Projected Test Year Ended
Entergy Arkansas, Inc.
March 31, 2015
Docket No. 15-015-U
(1)
LN
(2)
Account
1067
528001
Nuc Out Amort-Maint Supv & Eng
This account records the amortization of nuclear refueling outage
costs, specifically the cost of labor and expenses incurred in the
general supervision and direction of maintenance of nuclear
generation facilities (USOA 528). Nuclear refueling outage costs
are deferred during the outage and amortized over the estimated
period to the next outage because these refueling outage
expenses are incurred to prepare the units to operate for the next
operating cycle without having to be taken off line.
1068
529000
Maintenance Of Structures
This account shall include the cost of labor, materials used and
expenses incurred in the maintenance of structures, the book cost
of which is includible in account 321, Structures and
Improvements. (See USOA operating expense instruction 2.)
1069
530000
Maint Of Reactor Plant Equip
This account shall include the cost of labor, materials used and
expenses incurred in the maintenance of reactor plant, the book
cost of which is includible in account 322, Reactor Plant
Equipment. (See USOA operating expense instruction 2.)
1070
531000
Maintenance Of Electric Plant
1071
532000
Maint Of Misc Nuclear Plant
1072
532001
Nuc Out Amort-Maint Misc Nuc P
This account shall include the cost of labor, materials used and
expenses incurred in the maintenance of electric plant, the book
cost of which is includible in account 323, Turbogenerator Units,
and account 324, Accessory Electric Equipment. (See USOA
operating expense instruction 2.)
This account shall include the cost of labor, materials used and
expenses incurred in maintenance of miscellaneous nuclear
generating plant, the book cost of which is includible in account
325, Miscellaneous Power Plant Equipment. (See USOA
operating expense instruction 2.)
This account will capture costs currently captured in accounting
532, resource 590, amortization of outage costs.
1073
(3)
Account Title
Hydraulic Power Generation Expenses - Operation
1074
535000
Operating Supervision & Engin
1075
536000
Water For Power
1076
538000
Electric Expenses
1077
539000
Misc Hydro Power Generation
1078
540000
Rents
1079
(4)
Account Description
This account shall include the cost of labor and expenses incurred
in the general supervision and direction of the operation of
hydraulic power generating stations. Direct supervision of specific
activities, such as hydraulic operation, generator operation, etc.,
shall be charged to the appropriate account (See USOA operating
expense instruction 1).
This account shall include the cost of water used for hydraulic
power generation.
This account shall include the cost of labor, materials used and
expenses incurred in operating prime movers, generators, and
their auxiliary apparatus, switchgear, and other electric equipment,
to the point where electricity leaves for conversion for
transmission or distribution.
This account shall include the cost of labor, materials used and
expenses incurred which are not specifically provided for or are
not readily assignable to other hydraulic generation operation
expense accounts.
This account shall include all rents of property of others used,
occupied or operated in connection with hydraulic power
generation, including amounts payable to the United States for the
occupancy of public lands and reservations for reservoirs, dams,
flumes, forebays, penstocks, power houses, etc., but not including
transmission right of way. (See USOA operating expense
instruction 3.)
Hydraulic Power Generation Expenses - Maintenance
E-9 Page 89 of 99
APSC FILED Time: 4/24/2015 1:27:19 PM: Recvd 4/24/2015 1:11:27 PM: Docket 15-015-U-Doc. 41 Schedule E-9
Arkansas Public Service Commission
Chart of Accounts
Minimum Filing Requirements
Partially Projected Test Year Ended
Entergy Arkansas, Inc.
March 31, 2015
Docket No. 15-015-U
(1)
LN
(2)
Account
(3)
Account Title
1080
541000
Maintenance Supervision & Eng
This account shall include the cost of labor and expenses incurred
in the general supervision and direction of the maintenance of
hydraulic power generating stations. Direct field supervision of
specific jobs shall be charged to the appropriate maintenance
account. (See USOA operating expense instruction 1.)
1081
542000
Maintenance Of Structures
This account shall include the cost of labor, materials used, and
expenses incurred in maintenance of hydraulic structures, the
book cost of which is includible in Account 331, Structures and
Improvements. (See USOA operating expense instruction 2)
1082
543000
Maint Of Dams, Reservoirs & W
1083
544000
Maint Of Electric Plt
1084
545000
Maint Of Misc Hydraulic Plt
This account shall include the cost of labor, materials used, and
expenses incurred in maintenance of plant includible in Account
332, Reservoirs, Dams, and Waterways. (See USOA operating
expense instruction 2)
This account shall include the cost of labor, materials used and
expenses incurred in maintenance of plant includible in Account
333, Water Wheels, Turbines and Generators, and account 334,
Accessory Electric Equipment. (See USOA operating expense
instruction 2.)
This account shall include the cost of labor, materials used, and
expenses incurred in maintenance of plant, the book cost of which
is includible in Account 335, Miscellaneous Power Plant
Equipment, and Account 336, Roads, Railroads and Bridges. (See
USOA operating expense instruction 2.)
1085
(4)
Account Description
Other Power Generation Expenses - Operation
1086
546000
Operation Superv & Engineerin
this account shall include the cost of labor and expenses incurred
in the general supervision and direction of the operation of other
power generating stations. Direct supervision of specific activities,
such as fuel handling, engine and generator operation