Control Number : 43695
Item Number: 657
Addendum StartPage : 0
SOAH DOCKET NO. 473-15-1556
PUC DOCKET NO. 43695
APPLICATION OF SOUTHWESTERN
PUBLIC SERVICE COMPANY FOR
AUTHORITY TO CHANGE RATES
§
§
§
BEFORE THE STATE OFFICE
OF
ADMINISTRATIVE HEARINGS
VOLUMINIOUS WORKPAPERS
TO THE
DIRECT TESTIMONY
OF
WILLIAM B. MARCUS
ON BEHALF OF THE
-^
OFFICE OF PUBLIC UTILITY COUNSEL
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MAY 18, 2015
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Exhibit SPS-OPUC 3-10
Page I of 2
Docket No. 43695
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Exhibit SPS-OPUC 3-10
Page 2 of 2
Docket No. 43695
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QUESTION NO. OPUC 3-11:
Please provide the date atid time of class non-coincident peak load in the single highest hour
for the sum of the residential-RTX and residential-RSH groups (and the amount of each
group) in the test year and the three preceding years.
RESPONSE:
Please refer to Exhibit SPS-OPUC 3-11.
Preparer:
Sponsor:
Justin Vicar
Jannell E. Marks
PUC Docket No. 43695
SOAH Docket No, 473-15-1556
Southwestern Public Service Company's Response to
Of tce of Public Utility Counsel's Third Requestfor Information
-18-
Exhibit SPS-OPUC 3-11
Page 1 of 1
Docket No. 43695
Southwestern Public Service Company
Non-Coincident Peak Load
Line
No.
Year
2011
2012
2013
July 2013 -June 2014
Regular Res Space Heat
Jan - Dec
Total
RSHTX
RTX
Res Class Peak
902,790.31
335,267.59
567,522.72
7/27/11 17:00
6/27/1218:00 744,208.53 309,768.24 1,053,976.77
6/27/1318:00 699,585.26 325,906.31 1,025,491.57
6/29/14 17:00 710,071.48 298,412.31 1,008,483.79
146
SUPPLEMENTAL RESPONSE
QUESTION NO. OPUC 3-33:
Please identify gross plant and depreciation reserve associated with distribution capacitors,
by FERC account.
MARCH 25, 2015 SUPPLEMENTAL RESPONSE:
The following supplements SPS's initial response provided on January 28, 2015:
As described in SPS's initial response to Question No. 3-33, SPS's does not depreciate assets
in FERC Account 368 (which contains distribution capacitors and distribution line
transformers) by property unit. This means that the level of detail required to determine the
total amount of gross plant and depreciation reserve associated with distribution capacitors
versus distribution line transformers at a given point in time is not available for the account
in total. However, in a good faith attempt to provide the requested information, SPS has
developed an estimate of the amount of gross plant and depreciation reserve in FERC
Account 368 for distribution capacitors.
The estimate provided is based on the amount of gross plant and depreciation reserve that has
been unitized to date. "Unitization" is a process of dividing a work order into its various
parts. For instance, once the work order is placed in service, the project goes through the
unitization process in order to determine the property units, retirement units, and other
detailed information. Since a portion of the assets in FERC Account 368 have not completed
the unitization process, SPS is unable to determine the property unit of all assets in that
account, which is the information needed to identify the capacitor amounts. SPS estimates
that approximately $8 million of the plant balance provided in SPS's initial response to this
question have yet to go through the unitization process. SPS estimates that distribution
capacitors represent approximately 5% of that $8 million. Please note that
the unitization
process does not prevent an asset from depreciating as this occurs as soon as the work order
is placed in service.
Based on the estimation method described above, SPS estimates that of the information
initially provided in response to Question No. OPUC 3-33, distribution capacitors make up
$7,999,288 of gross plant and $3,021,541 of depreciation reserve. The following table
incorporates this estimate.
PUC Docket No. 43695
SOAH Docket No. 473-15-1556
Southwestern Public Service Company's Second Supplemental Response to
Office ofPublic Utility Counsel's Third Request forlnformation
Question No. 3-33
- 6-
FERC Account
368-Line Transformers
(Account Total)
Estimated Distribution
Capacitors included of FERC
368-Line Transformers
Remaining Distribution Line
Transformers included in
FERC 368-Line Transformers
Preparers:
Sponsor:
Gross Plant
at June 30, 2014
148,680,809
$
Depreciation Reserve
(including RWIP)
at June 30, 2014
$ 36,079,839
$
7,999,288
$
3,021,541
$
40,681,521
$
33,058,298
Jason Hegna, Brandon Kirschner
Lisa H. Perkett
PUC Docket No. 43695
SOAH Docket No. 473-15-1556
Southwestern Public Service Company's Second Supplemental Response to
Office of Public Utility Counsel's Third Request for Information
Question No. 3-33
- 7-
QUESTION NO. OPUC 3-22:
Please identify all costs of "Major Account Representatives" (defined as company employees
assigned specifically to serve large customers) in the test year by FERC Account. Include
non-labor expenses of these staffers. Divide costs into between the service company and
SPS. Identify the witness(es) and "affiliate class(es)" where service company costs in these
areas are found.
RESPONSE:
The total company Test Year costs for Major Account Representatives are provided in the
table below. All costs originate in SPS and are native costs; there are no service company
costs.
FERC
Account
FERC Description
408.1
426.1
426.5
908
912
Tax Oth than Inc Tx-Ut
Donations
Other Deductions
Customer Asst Expense
Sales Demo & Sales
925
A&G Injuries &
Damages
926
Grand Total
Preparers:
Sponsors:
A&G Pen & Ben
Labor
Non-
Grand
Labor
Total
65,222
767,057
2,775
739
19,300
84,974
603
9,561
296,517
1,141,132
65,222
739
19,300
852,031
3,379
9,561
105,617
296,51.7
1,246,749
Seth Thomason, Raynard A. Gray
Evan D. Evans, Raynard A. Gray
PUC Docket No. 43695
SOAHDocket No. 473-15-1556
Southwestern Public Service Company's Response to
Office ofPublic Utility Counsel's Third Request forInformation
-30-
QUESTION NO. OPUC 3-23:
Please identify the classes that are served by "Major Account Representatives" and estimate
the approximate percentage of time spent on each class.
RESPONSE:
The account managers ("Major Account Representatives") serve primarily three customer
classes. These are: (1) Secondary General; (2) Primary General; and (3) Large General
Service - Transmission. Time is not tracked in such a way that one could discern the
percentages of time spent with each class,
Preparer:
Sponsor:
Seth Thomason
Evan D. Evans
PUCDocket No. 43695
SdAHDocket No. 473-15-I50
Southwestern Public Servtce Company's Response to
Office ofAublic Utility Counsel's Third Request for Information
-31-
9
QUESTION NO. OPUC 3-37:
Please estimate the amount of Texas revenue from returned check charges by class (or at
least divided into residential and non-resxdential).
RESPONSE:
The Texas revenue from returned check charges for the Test Year was $122,869.53.
Although the return check charge revenue is not .recorded by customer class, there where,
7,152 (96%) instances ofreturned checks for residential customers and 312 (4%) instances of
returned checks for non-residential customers.
Preparer:
Sponsor:
Adrian Casillas
Richard M. Luth
PUC.bocket No. 43695
SDAHDocket No. 473-15-1556
Southwestern Public Service Company's Response to
Office ofPublic Utility Counsel's Third Request forlnformation
-4S-
10
QUESTION NO. TIEC 2-13:
Please explain the reasons for each of the following changes that SPS has made to its class
cost-of-service study since Docket No. 42004 and quantify the impact of each change by
retail customer class:
a.
Use of the 4CP load factor to weight the average demand portion of the AED-4CP
allocation factors.
b.
The allocation of radial transmission lines primarily based on the AED-4CP
allocation factors.
c.
The allocation of FERC Account No. 902 (meter reading costs).
d.
The allocation of FERC Account No. 924 (property insurance) based on total plant in
service.
RESPONSE
a.
SP S proposed the 4CP load factor to weight the average demand portion of the AED4CP allocation factors so that the average demand portion is consistent with the four
months in the Test Year that are reflected in the AED-4CP. Additionally, the 4CP
load factor is consistent with the Commission's Order in Docket No. 40443,
Southwestern Electric Power Company's recent rate case. Please refer to Exhibit
SPS-TIEC 2-13(a) for the impacts on AED-4CP allocation factors byretail customer
class.
b.
In both Docket Nos. 42004 and 43695, an AED-4CP allocation was applied to radial
lines that served more than one customer class; however in Docket No. 42004, radial
lines serving more than one customer class were allocated to only those customer
classes served on those radial lines. Please refer to the Direct Testimony of Richard
M. Luth (Vol. RD1, pages 42-44 of 411) for an explanation of the change to the
allocation of radial transmission lines. As indicated in Mr. Luth's testimony, SPS
does not have sufficient information to adequately quantify the relative use by
customer class on specific radial lines providing service to multiple customer classes.
Please refer to Exhibit SPS-TIEC 2-13(b) for the impact on the allocation of radial
lines using the approach utilized in Docket No. 42004 compared to the approach
utilized in this filing.
c.
Please refer to the Direct Testimony of Richard M. Luth (Vol. RD 1, page 56 of 411)
for an explanation of the change to the allocation of FERC Account 902. Please refer
PUC Docket No. 43695
SOAHDocket No. 473-15-1556
Southwestern Public Service Company's Response to
Texas Industrial Energy Consumer's Second Request for Information
-19-
to Exhibit SPS-TIEC 2-13(c) for a quantification of the change in meter reading
allocation methodology between Docket No. 42004 and Docket No. 43695.
d.
Preparers:
Sponsor:
SPS allocated FERC Account 924, Property Insurance, according to total plant in
service, compared to net plant in service in Docket No. 42004. SPS believes that it is
appropriate to allocate Property Insurance according to total plant in service to better
reflect the cost of insuring the replacement cost of damage to plant in service. Please
refer to Exhibit SPS-TIEC 2-13(d).
Jeff Comer, Ian Fetters, Richard M. Luth
Richard M. Luth
PUCDocketNo, 43695
SOAHDocket No. 473-15-1556
Southwestern Public Service Company's Response to
Texas Industrial Energy Consumer's Second Requestfor Information
- 20-
12
Exhibit SPS-TIEC 2-13(a)
Page 1 of 9
Docket No. 43695
2-13 (a) 4CP
Southwestern Public Service Company
Adjusted Base Period, Adjusted for Weather, Retail, and Wholesale Adjustments
Line
No.
Texas Retail
AVERAGE AND EXCESS CALCULATION
FOR THE TEST PERIOD ENDED: JUNE 30, 2014
Residential
Total
RTX
Texas
I
Hours in Year
2
4-CP Production
3
4
5
6
7
8
9
10
Average
Excess
Sys. Excess
AED 4-CP
Sum of 4-CP Check
Sum of Average Check
Sum of Sys Excess check
8,760
2 , 367 , 380
1 , 727 , 087
644 , 316
640 ,293
2,367,380
2,363,772
2,367,380
1,727,087
640,293
Average allocation
Excess allocation
Total allocation
11
4-CP Transmission
12
13
14
15
16
Average
Excess
Sys. Excess
AED 4-CP
Small
General
Service
Area
Lighting
Street
Lighting
Residential
RHTX
2,380,134
1,727,087
657,104
653,047
2,380,134
2,376,561
17
Sum of 4-CP Check
2,380,134
18
19
Sum of Average Check
Sum of Sys. Excess check
1,727,087
653,047
497,293
212,331
284,962
283,183
520,077
183,591
98,201
85,389
84,856
188,878
0
4,355
0
0
4,161
0
3,275
0
0
3,129
55,233
34,992
20,241
20,115
55,964
8.57%
13.40%
21.97%
3.96%
4.01%
7.98%
0.18%
0000/0
0.18%
0.13%
0.00%
0.13%
1.41%
0.95%
2.36%
505,509
212,331
293,178
291,368
538,178
186,480
98, 201
88,279
87,734
194,201
0
4 , 355
0
0
4,086
0
3 , 275
0
0
3,072
56,281
34,992
21 , 290
21 , 158
57,445
Average allocation
Excess allocation
Total allocation
8 . 37%
14 .24%
22.61%
4 CP (MW)
System load MWh
System load factor
PROD
System
4CP
4,513
27,558,186
69.70%
3.87%
4290/a
8.16%
0.17%
0.00%
017%
0.13%
0.00%
0.13%
1.38%
1.03%
241%
TRANS
System
4CP
5,383
32,106,001
68.08%
042
13
Exhibit SPS-TIEC 2-13(a)
Page 2 of 9
Docket No. 43695
Southwestern Public Service Company
2-13 (a) 4CP
Adjusted Base Period, Adjusted for Weather, Retail, and Wholesale Adjustments
Texas Retail
Line
No.
AVERAGE AND EXCESS CALCULATION
FOR THE TEST PERIOD ENDED: JUNE 30, 2014
Small School
Large
L a rge
Small Mumicipal
Municipal
Municipal
Service
[Secondary]
[Primary]
Interrup tible
SAS-4
Secondary
G enera l
Service
Large
School
Large
g
School
[Primary]
1
2
3
4
5
6
7
8
2,800
2 , 333
468
465
2,750
26,559
20 , 095
6,464
6,423
26,396
5,600
3,843
1 , 757
1,746
5,628
18,199
18,199
0
0
17,389
436,833
286,806
150,027
149 , 091
441,034
33,206
22,313
10,893
10 , 825
33,445
583
341
242
241
595
0.09%
0.02%
0.12%
0.81%
030%
1.11%
0.16%
o
0.08%
0 . 24%
0.73%
°
0.00%
0 . 73/n
1158"/0
7.05%
18.63%
0.90%
0.51%
1.41%
0,01 %
0.01%
003/
9
10
11
12
13
14
15
16
17
18
2,843
2,333
510
507
2,778
26,951
20 , 095
6,855
6,813
26,780
5,671
3 , 843
1 , 828
1 , 817
5,719
0.09%
0 . 02%
0.12%
0.79%
0.15%
18,199
18,199
0
0
17,075
443,864
286,806
157,058
156,088
450 , 676
33,687
22,313
11,374
11,304
34 ,085
592
341
251
249
610
0.72%
0.00%.
0 . 72%
11.31%
7.63%
18.93%
0.88%
0
1.43%
0.01%
0.01 %
003/°
19
1.13%
024%
043
14
Exhibit SPS-TIEC 2-13(a)
Page 3 of 9
Docket No. 43695
2-13 (a) 4CP
Southwestern Public Service Company
Adjusted Base Period, Adjusted for Weather, Retail, and Wholesale Adjustments
Line
No.
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
Texas Retail
AVERAGE AND EXCESS CALCULATION
FOR THE TEST PERIOD ENDED: JUNE 30, 2014
Transmission
Primary
BB
Sub-Trans
General
LGS
LGS
Service
276,663
272,246
4,417
4,390
265,037
148,012
133,641
14,371
14,282
143,686
679,200
614,116
65,084
64,677
659,212
10.99%
0.21%
11.20%
5.39%
0.68%
6.07%
24.79%
3.06%
27.85%
281,103
272,246
8,857
8,802
265,671
148,921
133,641
15,280
15,186
143,053
666,460
614,116
52,344
52,021
636,704
10.73%
043%
11.16%
5.27%
0740/6
6.01%
24.21%
2.54%
26.75%
100.00%
100.00%
044
1-5
Exhibit SPS-TTEC 2-13(a)
Page 4 of 9
Docket No. 43695
Southwestern Public Service Company
2-13 (a) tCP
Adjusted Base Period, Adjusted for Weather, Retail, and
Wholesale Adjustments
Line
No
Texas Retail
AVERAGE AND EXCESS CALCULATION
FOR THE TEST PERIOD ENDED: JUNE 30 2014
Total
Res idential
Texas
RTX
1
Hours in Year
2
3
4
5
6
4-CP Production
Average
Excess
Sys Excess
AED 4-CP
7
8
9
10
Sum of 4-CP Check
Sum of Average Check
Sum of Sys. Excess check
4-CP Transmission
Average
Excess
Sys. Excess
AED4-CP
Sum of 4-CP Check
Sum of Average Check
Sum of Sys Excess check
Average allocation
Excess allocation
Total allocation
MAX PEAK ( MW)
System load MWh
System load factor
Street
Lighting
Area
Lighting
Small
General
Service
8,760
2,367,380
1,727,087
644,316
640,293
2,367,380
2,363,772
2,367,380
1,727,087
640,293
Average allocation
Excess allocation
Total allocation
11
12
13
14
15
16
17
18
19
Residential
RHTX
2,380,134
1,727,087
657,104
653,047
2,380,134
2,376,561
2,380,134
1,727,087
653,047
497,293
212,331
284,962
283 , 183
533,405
183,591
98,201
85,389
84 , 856
192,036
0
4,355
0
0
4,056
0
3,275
0
0
3 , 050
55,233
3 4 , 992
20,241
20,115
56 , 430
8.35%
14.18%
22. 53%
3.86%
4.25%
8 . 11° /0
017%
0.00%
017%
0.13%
0
0.00%
0.13%
o
1.38%
1.O1 /o
238%
505,509
212,331
293,178
291,368
563,899
186 ,480
98,201
88 , 279
87 , 734
200,367
0
4 , 355
0
0
3,886
0
3 , 275
0
0
2 , 921
56,281
34,992
21,290
21,158
58 , 411
7 96 0o%
15.73 /0
23 . 69%
3•68%
4.74%
°
8.42%
0.16%
0.00%
0.16%
0.12%
000%
0.12%
1 31%
1.14%
2.45%
PROD
TRANS
System
MAX PEAK
4,630
27 , 558 , 186
System
MAX PEAK
5,661
67 . 94%
32,106,001
64.74%
045
16
Exhibit SPS-TIEC 2-13(a)
Page 5 of 9
Docket No. 43695
2-13 (a)1CP
Southwestern Public Service Company
Adjusted Base Period, Adjusted for Weather, Retail, and Wholesale Adjustments
Texas Retail
Line
No,
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
AVERAGE AND EXCESS CALCULATION
FOR THE TEST PERIOD ENDED: JUNE 30, 2014
Large
Large
Small School
Municipal
Municipal
Small Mumicipal
[Primary]
[Secondary]
Service
2 , 800
2 ,333
468
465
2,723
26,559
20,095
6,464
6,423
26,329
5,600
3,843
1,757
1,746
5,649
Interruptible
SAS-4
18,199
18,199
0
0
16,949
Secondary
General
Service
436,833
286,806
150,027
149,091
443,821
Large
School
[Secondary]
33,206
22,313
10,893
10,825
33,611
Large
School
[Primary]
583
341
242
241
602
0 . 09%
0 . 02%
0.12%
0.79%
032%
1.11%
0 15%
0.09%
0.24%
0.72%
0.00%
072%
11.28%
7.46%
18.75%
0.88%
0.54%
1.42%
0.01%
0.01%
0.03%
2,843
2,333
510
507
2 , 733
26,951
20,095
6,855
6,813
26 , 684
5,671
3,843
1,828
1,817
5,763
18,199
18,199
0
0
16,237
443,864
286,806
157,058
156 ,088
456,482
33,687
22,313
11,374
11,304
34,435
592
341
251
249
624
17
18
19
009%
0 . 03%
0.11%
0.75%
0,37%
1.12%
0.14%
0.10%
0.24%
0.68%
0.00%
0.68%
10.75%
8.43%
1918%
0.84%
0.61%
1.45%
0.01%
0.01%
0.03%
046
17
Exhibit SPS-TIEC 2-13(a)
Page 6 of 9
Docket No. 43695
Southwestern Public Service Company
2-13 (a) ICP
Adjusted Base Period, Adjusted for Weather, Retail, and Wholesale Adjustments
Line
No.
Texas Retail
AVERAGE AND EXCESS CALCULATION
FOR THE TEST PERIOD ENDED: JUNE 30, 2014
Primary
Transmission
General
Sub-Trans.
BB
Service
LGS
LGS
2
3
276,663
272,246
148,012
133,641
679,200
614,116
4
5
4,417
4,390
14,371
14,282
6
7
8
9
10
258,745
65,084
64,677
141,387
648,587
10.71%
022%
10.93%
5.26%
0.72%
5.97%
24.16%
324%
27.40%
11
12
13
14
15
16
17
18
19
281,103
272,246
8,857
8,802
254,200
148,921
133,641
15,280
15,186
138,745
666,460
614,116
52,344
52,021
614,748
10.20%
501%
0.48%
10.68%
23.02%
0.82%
5.83%
2.81%
25.83%
100.00%
100 00%
047
18
Exhibit SPS-TIEC 2-13(a)
Page 7 of 9
Docket No. 43695
2•13 (a) Compare
Southwestern Public Service Company
Adjusted Base Period, Adjusted for Weather, Retail, and Wholesale Adjustments
ine
No.
Texas Retail
AVERAGE AND EXCESS CALCULATION
FOR THE TEST PERIOD ENDED: JUNE 30, 2014
Residential
Total
RTX
Texas
1
Hours in Year
2
3
4
5
6
7
8
9
10
4-CP Production
Average
Excess
Sys. Excess
AED4-CP
Sum of 4-CP Check
Sum of Average Check
Sum of Sys. Excess check
8,760
0
0
0
0
(13 , 328)
0
0
0
0
0
0
4-CP Transmission
12
Average
13
14
15
16
17
18
19
Excess
Sys. Excess
AED4-CP
Sum of 4-CP Check
Sum of Average Check
Sum of Sys. Excess check
Average allocation
Excess allocation
Total allocation
MAX PEAK (MW)
System load MWh
System load factor
0
0
0
0
(3,158)
0
0
0
0
105
0
0
0
0
79
0
0
0
0
(466)
0
0
0
0
Average allocation
Excess allocation
Total allocation
11
mall
General
Service
rea
Lighting
treet
Lighting
esidential
RHTX
0
0
0
0
022%
-0 . 78%
-056%
0.10%
-0.23%
-0 13%
0.00%
0.00%
0.00%
0.00%
0.00%
0.00%
0.04%
-006%
-0.02%
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
(966)
0.07%
-0 11%
-0.04%
0
0
(25 , 721)
(6,166)
201
0
151
0.19%
-0.45%
-0.26%
0,01"/0
0.00%
0.01%
0.01%
0.00%
0.01%
0
0
0
0
0 . 41%
-1 . 49%
-108%
PROD
System
MAX PEAK
4,630
27,558,186
67.94%
TRANS
System
MAX PEAK
5,661
32,106,001
64 74%
048
19
Exhibit SPS-TIEC 2-13(a)
Page 8 of 9
Docket No. 43695
Southwestern Public Service Company
2-13 (a) Compare
Adjusted Base Period, Adjusted for Weather, Retail, and
Wholesale Adjustments
Line
No.
2
3
4
5
6
Texas Retail
AVERAGE AND EXCESS CALCULATION
FOR THE TEST PERIOD ENDED: JUNE 30 2014
Small School
Large
La rge
Small Mumicipal
Municipal
Munici p al
Service
[Secondary]
[Primary]
0
0
0
0
0
0
0
0
0
0
26
67
(21)
0.00%
0 00%
0.00/
0.02%
00
0 . 02/
0.00%
0.00%
0.00%
0
In t errupt ib le
SAS -4
0
Secondary
General
Large
School
Service
[Secondary)
Large
School
- [Primary ]
0
0
440
0
0
0
0
(2,787)
0
0
0
0
(166)
0
(7)
o
0 02%
0.00%
0 . 02%
0.29%
-0.41%
012/0
002%
-0.03%
0.01%
0.00%
0 00%
o
0.00%
0
0
0
0
(349)
0
0
0
0
(15)
0.04%
-0.06%
-001%
0.00%
0.00%
o
0.00%
0
0
0
8
9
10
11
12
13
14
15
16
0
0
0
0
46
0
0
0
0
0
0
0
0
0
96
(44)
839
0
0
0
0
(5,805)
0.04%
.
-003%
0.00%
0.01 %
0.04%
0.00%
0.04%
0.56%
0.80%
0.24%
0
17
18
19
0.00%
000%
0.00%
0 . 00%
049
20
Exhibit SPS-TIEC 2-13(a)
Page 9 of 9
Docket No. 43695
2-13 (a) Compare
Southwestern Public Service Company
Adjusted Base Period, Adjusted for Weather, Retail, and Wholesale Adjustments
Line
No.
2
3
4
5
6
7
8
9
10
Texas Retail
AVERAGE AND EXCESS CALCULATION
FOR THE TEST PERIOD ENDED: JUNE 30, 2014
Transmission
Primary
BB
Sub-Trans.
General
LGS
LGS
Service
0
0
0
0
6,293
0
0
0
0
2,299
0
0
028%
-0.01%
0.27%
0.14%
-0.04%
0.10%
0.63%
-0.18%
0.45%
11
12
13
14
0
0
0
0
0
0
0
0
0
15
11,471
4,307
21,957
0
0
10,625
0.00%
0
0
0
16
17
18
19
0.53%
-0,05%
0.48%
0.26%
-0 08%
0.18%
1.19%
-0.27%
0.92%
0.00%
050,
21
QUESTION NO. Staff 2-56:
With regards to contractors that provide vegetation management services for the SPS's
distribution system in the SPS region:
a.
b.
c.
Provide the total dollar amount requested for the test year.
Identify the FERC accounts that are affected by these expenses.
Explain if these expenses are direct or are an allocated. If such revenues are
allocated, explain the allocation and justify the amount of the revenues.
RESPONSE:
a-b.
The following expenses were directly incurred by SPS for vegetation management
contractor services:
FERC
escrip tion
Account
Test Year
Amount
(Total
Company)
Dist Oper Overhead Lines
Dist Oper Misc Exp
Dist Mtc. of Station Equipment
583
588
592
479,109
23,607
124.325
Dist Mtc of Overhead Lines
593
2,498,053
Total
$3,125,094
The total Test Year amounts can be allocated to the Texas retail jurisdiction in
accordance with the jurisdictional allocators set forth on pages 269-270 of
Attachment DAB-RR-2 to the Direct Testimony of Deborah A. Blair (Vol. RR16,
pages 412-413 of 426).
c.
Preparer:
Sponsors:
There are no allocated expenses.
Elizabeth Gauna-Giacomini
Brad E. Baidridge, Deborah A. Blair
PUC Docket No. 43695'
SOAHDocket No. 473-15-1556
Southwestern Public Service Company's Response to
Commission Staffs Second Requestfor Information
-70-
QUESTION NO. Staff 2-57
With regards to distribution line vegetation management in the SPS region:
Provide the total dollar amount requested for the most recent calendar or fiscal year,
a.
the test year, and each of the four years before the test year.
b.
Identify the FERC accounts that are affected by these expenses.
c.
Explain if these expenses are direct or are an allocated. If such revenues are
allocated, explain the allocation and justify the amount of the revenues.
RESPONSE:
a-b.
The following expenses were directly incurred by SPS for distribution line vegetation
management:
Year
Total Company
Vegetation Management
Distribution Expense
Test Year
2014
2013
$2,498,053
$2,513,603
$2,296,862
2012
2011
$2,082,447
$2,373,189
2010
$3,471,534
All expenses are recorded in FERC Account No. 593.
The total Test Year amounts can be allocated to the Texas retail jurisdiction in
accordance with the jurisdictional allocators set forth on pages 269-270 of
Attachment DAB-RR-2 to the Direct Testimony of Deborah A. Blair (Vol. RR16,
pages 412-413 of 426).
c.
Preparer:
Sponsors:
There are no allocated expenses.
Elizabeth Gauna-Giacomini
Brad E. Baldridge, Deborah A. Blair
PUC Docket No. 43695
SDAHDocket No. 473-15-1556
Southwestern Public Service Company's Response to
Commission Staff s Second Request for Information
-71-
23
^' ^*- ^• s+ e 1,+ t: ^
PUC DOCKET NO. 39896
SOAH DOCKET NO. 473-12-2979
2012 Noy -2 AM 9: 24
Pu„_: ;
F^^.^tG vt^ i?^
APPLICATION OF ENTERGY TEXAS,
INC. FOR AUTHORITY TO CHANGE
RATES, RECONCILE FUEL COSTS,
AND OBTAIN DEFERRED
ACCOUNTING TREATMENT
§
§
§
§
. ^w
PUBLIC UTILITY COMMISSION
OF TEXAS
§
ORDER ON REHEARING
This Order addresses the application of Entergy Texas, Inc. for authority to change rates,
reconcile fuel costs, and defer costs for the transition to the Midwest Independent System
Operator (MISO). In its application, Entergy requested approval of an increase in annual baserate revenues of approximately $111.8 million (later lowered to $104.8 million), proposed tariff
schedules, including new riders to recover costs related to purchased-power capacity and
renewable-energy credit requirements, requested final reconciliation of its fuel costs, and
requested waivers to the rate-filing package requirements.
On July 6, 2012, the State Office of Administrative Hearings (SOAH) administrative law
judges (ALJs) issued a proposal for decision in which they recommended an overall rate increase
for Entergy of $28.3 million resulting in a total revenue requirement of approximately $781
million. The ALJs also recommended approving total fuel costs of approximately $1.3 billion.
The ALJs did not recommend approving the renewable-energy credit rider and the Commission
earlier removed the purchased-power capacity rider as an issue to be addressed in this docket.'
On August 8, 2012, the ALJs filed corrections to the proposal for decision based on the
exceptions and replies of the parties.2 Except as discussed in this Order, the Commission adopts
the proposal for decision, as corrected, including findings of fact and conclusions of law.
Parties filed motions for rehearing on September 25 and October 4, 2012 and filed replies
to the motions for rehearing on October 15, 2012. The Commission considered the motions for
' Supplemental Preliminary Order at 2, 3 (Jan. 19, 2012).
2
Letter from SOAH judges to PUC (Aug. 8, 2012).
^
24
PUC Docket No. 39896
SOAH Docket No. 473-12-2979
Order on Rehearing
Page 8 of 44
The Commission agrees with the ALJs, but modifies finding of fact 133 to specifically
include the decision that an additional reduction should be made to account for the FICA taxes
Entergy would have paid on the disallowed financially-based incentive compensation.
The
Commission notes that this reduction for FICA taxes is reflected in the schedules attached to this
Order.29
G. Affiliate Transactions
OPUC argued that Entergy's sales and marketing expenses exclusively benefit the larger
commercial and industrial customers, but the majority of the sales, marketing, and customer
service expenses are allocated to the operating companies based on customer counts. Therefore,
the majority of these expenses are allocated to residential and small business customers. OPUC
argued that it is inappropriate for residential and small business customers to pay for these
expenses.30 The ALJs did not adopt OPUC's position on this issue.
The Commission agrees with OPUC and reverses the proposal for decision regarding
allocation of Entergy's sales and marketing expense and finds that $2.086 million of sales and
marketing expense should be reallocated using direct assignment.
The Commission has
previously expressed its preference for direct assignment of affiliate expenses. 31
The
Commission finds that the following amounts should be allocated based on a total-number-ofcustomers basis: (1) $46,490 for Project E10PCR56224 - Sales and Marketing - EGSI Texas;
(2) $17,013 for Project F3PCD10049 - Regulated Retail Systems O&M; and (3) $30,167 for
Project F3PPMMALI2 - Middle Market Mkt. Development. The remainder, $1,992,475, should
be assigned to (1) General Service, (2) Large General Service and (3) Large Industrial Power
Service.32 The reallocation has the effect of increasing the revenue requirement allocated to the
large business class customers and reduces the revenue requirement for small business and
residential customers. New finding of fact 164A is added to reflect the proper allocation of these
affiliate transactions.
29 See Commission Number Run-Memorandum at 3 (Aug. 28, 2012).
'0 Direct Testimony of Carol Szerszen, OPUC Ex. I at 44-45.
31 Application of Central Power and Light Company for Authority to Change Rates, Docket No. 14965,
Second Order on Rehearing at 87, COL 29 (Oct. 16, 1997).
32 Direct Testimony of Carol Szerszen, OPUC Ex. 1 at Schedule CAS-7.
25
PUC Docket No. 39896
SOAH Docket No. 473-12-2979
Order on Rehearing
Page 28 of 44
L.L.C.; Entergy Arkansas, Inc.; Entergy Louisiana, LLC; Entergy Mississippi, Inc.;
Entergy Operations, Inc.; and non-regulated affiliates.
163.
ESI follows a number of processes to ensure that affiliate charges are reasonable and
necessary and that ETI and its affiliates are charged the same rate for similar services.
These processes include: (a) the use of service agreements to define the level of service
required and the cost of those services; (b) direct billing of affiliate expenses where
possible; (c) reasonable allocation methodologies for costs that cannot be directly billed;
(d) budgeting processes and controls to provide budgeted costs that are reasonable and
necessary to ensure appropriate levels of service to its customers; and (e) oversight
controls by ETI's Affiliate Accounting and Allocations Department.
164.
Affiliates charged expenses to ETI through 1292 project codes during the test-year.
164A. The $2,086,145 in affiliate transactions related to sales and marketing expenses should be
reallocated using direct assignment. The following amounts should be allocated to all
retail classes in proportion to number of customers:
(1) $46,490 for Project
E10PCR56224 - Sales and Marketing - EGSI Texas; (2) $17,013 for Project
F3PCD10049 - Regulated Retail Systems O&M; and (3) $30,167 for Project
F3PPMMALI2 - Middle Market Mkt. Development. The remainder, $1,992,475, should
be assigned to (1) General Service, (2) Large General Service and (3) Large Industrial
Power Service.
165.
ETI agreed to remove the following affiliate transactions from its application:
(1) Project F3PPCASHCT ( Contractual Altemative/Cashpo) in the amount of $2,553;
(2) Project F3PCSPETEI ( Entergy-Tulane Energy Institute) in the amount of $14,288;
and (3) Project F5PPKATRPT ( Storm Cost Processing & Review) in the amount of $929.
166.
The $356,151 (which figure includes the $112,531 agreed to by ETI) of costs associated
with Projects F5PCZUBENQ (Non-Qualified Post Retirement) and F5PPZNQBDU (Non
Qual Pension/Benf Dom Utl) are costs that are not reasonable and necessary for the
provision of electric utility service and are not in the public interest.
167.
The $10,279 of costs associated with Project F3PPFXERSP (Evaluated Receipts
Settlement) are not normally-recurring costs and should not be recoverable.
26
QUESTION NO. OPUC 7-2:
For each Secondary General Service, Municipal, and School customer in the load research
sample of SPS under 500 kW, please provide the following information:
a.
A customer identifier (you need not identify the customer to us, but provide a unique
number for each customer for data base tracking and for our reference if we need to
refer to individual customer data to clarify issues with SPS).
b.
Number of valid days of data by season (summer June-September, remainder of
year).
c.
Energy in each month of the test year.
d.
Test year monthly maximum demands of the customer.
e.
Monthly maximum demands of the customer in the year immediately preceding the
test year (for our use in ratchet analysis).
f.
Time of the test year monthly demand of the customer (if available).
g.
Customer demand at the time of the monthly coincident peak for each month in the
test year.
h.
Customer demand at the time of the monthly class non-coincident peak for each
month in the test year.
L
Any available information on the type of customer (e.g., school, water pump, office
building, restaurant).
j.
The customerweighting factor used to develop the entire class profile from the
sample, recognizing that the sample is stratified.
k.
Whether the customer is currently subject to the "Rule of 80" for calculation of
billing demand.
RESPONSE:
Please refer to Exhibit SPS-OPUC 7-2(V)(CD), provided on the enclosed CD. All individual
customer IDs have been masked. Please note that no information is available for subpart (i).
Preparer:
Sponsor:
Justin Vicars
Jannell E. Marks
PUC Docket No. 43695
SOAIY DooketNo. 473-15-1556
Southwestern Public Service Company's Response to
Office of Public Utility Counsel's Seventh Request for Information
- 7-
27
Southwestern Public Service CompanySummary Data for Secondary General
OPUC Calcs
Load Research Sample Data
Exhibit SPS-OPUC 7-2(V)(CD)
Page 1 of 4
Docket No. 43695
OPUC 7-2 values for analysis
summary data for SG collected
CustID
SG256
SG228
SG223
SG250
SG168
SG91
SG150
SG 174
SG24
SG279
SG208
SG284
SG140
SG96
SG221
SG226
SG136
SG229
SG121
SG 105
SG280
SG264
SG114
SG225
SG22
SG272
SG36
SG17
SG177
SG169
SG240
SG101
SG166
SG164
SG107
SG142
SG188
SG43
SG101
SG209
SG274
SG222
SG12
SG99
SG237
SG269
SG212
SG 135
SG106
Weight
0.40376
0.29470
0.29470
0.40376
0.08418
0.29470
0.08418
0.08418
0.29470
0.40376
0.40376
0.40376
0.40376
0.40376
0.14992
0.29470
0.40376
0.40376
029470
0.29470
0.40376
0.08418
0.29470
0.04080
004080
0.02665
040376
0.04080
0.02665
0.14992
0.14992
0.29470
0.40376
0.40376
0,04080
0.40376
0,40376
0.29470
0.29470
0.40376
0.04080
0.29470
0.08418
0.40376
0.08418
0.29470
0.29470
029470
0.29470
4CP
average
demand
0
1.025
0.4875
0.09
0.135
7.035
0.27
0.35
5.1875
4.3
0.0075
7.8125
0.505
0.745
9.99
14.725
0 18
2.8475
12.365
0.09
1.1925
71.4975
0.005
209.04
30.84
1.6875
5.78
2.125
11.1
59.6525
18.065
9.8025
2.675
14.2725
59.58
22.125
15.4925
24.465
9.605
4.3
117
25.9425
100.5525
5.8025
18.09
11.3925
11.7625
10.545
16.125
4 summer
average
billing
4CP
demand
coincidence
0.685
0.0%
35.4425
2.9%
39.5825
1.2%
5.2475
1.7%
21.12
0.6%
65.2825
10.8%
47.43
0.6%
70075
5.0%
50.195
10.3%
29.5575
14.5%
2.0025
0.4%
15.37
50.8%
6.865
7.4%
3.12
23.9%
66.69
15.0%
53.6225
27.5%
1.395
12.9%
8.2375
34.6%
55.4325
22.3%
3
3.0%
3.585
33.3%
238.1925
30.0%
20.2725
0.0%
294.9
70.9%
148.8
20.7%
20.7575
8.1%
12.0325
48.0%
11.98
17.7%
21.84
50.8%
98.1475
60.8%
80.6225
22.4%
22.185
44.2%
13.8975
19.2%
18.595
76.8%
192.78
30.9%
23.595
93.8%
22.415
69.1%
26.165
93.5%
19.05
50.4%
7.355
58.5%
213.96
54.7%
31.55
82.2%
209.5425
48.0%
7.4925
77.4%
46.89
38.6%
14 7375
77.3%
18.15
64.8%
12.705
83.0%
26 9125
59.9%
summer
average
energy
2
148.55
536.275
80.95
350.95
1703.025
1430.075
225.175
1674.775
1347.475
98.475
923.975
489.425
242.325
5590.4
4714
138.6
875.05
6094.475
337.7
410.45
27687.775
2494.2
36316.275
19243.675
2765.775
1613.6
1614.15
2965.075
13500.15
12083.4
3424.725
2175.425
3239.025
34604.475
4258.625
4106.95
4845.475
3575.05
1404.95
41557.975
6185.125
42782.125
1532.575
9802.7
3090.85
3811
2737.8
5802.925
summer
August
Customer NCP
load factor Class NCP demand
coincidence
0.4%
0
0
0.6%
0.04
37.8
0.1%
1.9%
0.27
19.44
14%
2.1%
0.1
0.19
52.6%
2.3%
0.09
2.97
3.0%
3.6%
1.76
12.96
13.6%
41%
26.88
49.92
53.8%
4.4%
0
0
4.6%
0.61
40.55
1.5%
6.2%
6.16
28.05
22.0%
6.7%
2.2
0
0.0%
8.2%
0
15.26
0.0%
9.7%
0.15
8.64
1.7%
10.6%
0.1
3.79
2.6%
11.5%
27
47.04
57.4%
12.0%
4.68
42.66
11.0%
13.6%
0.18
3.19
5.6%
14.5%
3.17
8.48
37.4%
15.0%
7.52
80.51
9.3%
15.4%
0.12
0.24
50.0%
15.6%
126
2.26
55.8%
15.9%
63.84
112.32
56.8%
16.8%
0.01
15.09
0.1%
16.8%
233.52
277.68
84.1%
17.7%
88.92
162.72
54.6%
18.2%
8.51
15.93
53.4%
18.3%
4.84
15.04
32.2%
18.4%
0.58
8.1
7.2%
18.5%
5.76
15.36
37.5%
18.8%
64.44
141.08
45.7%
20.5%
9.61
83.48
11.5%
21.1%
8.93
14.98
59.6%
21.4%
2.7
13
208%
23.8%
21.15
21.21
99.7%
24.5%
66.96
195.12
34.3%
24.7%
22.8
24.88
91.6%
25.0%
13.01
22.62
57.5%
25.3%
26.79
26 88
99.7%
25.6%
7.76
19
40.8%
26.1%
4.39
8.9
49.3%
26.5%
146.16
256.32
57.0%
26.8%
21.31
32.19
662%
27.9%
162.54
211.32
76.9%
27.9%
5.14
8.31
61.9%
28.6%
20.52
21.24
96.6%
28.7%
9.09
15.34
59.3%
287%
18.54
18.69
99.2%
29.4%
11
12.66
869%
29.5%
23.34
30.21
77.3%
28
Southwestern Public Service CompanySummary Data for Secondary General
OPUC Calcs
Load Research Sample Data
OPUC 7-2 values for analysis
Exhibit SPS-OPUC 7-2(V)(CD)
Page 2 of 4
Docket No. 43695
summary data for SG collected
CustID
SG246
SG227
SG52
SG259
SG152
SG75
SG230
SG134
SG62
SG145
SG293
SG295
SG296
SG297
SG299
SG300
SG303
SG305
SG307
SG308
SG310
SG311
SG312
SG313
SG314
SG315
SG318
SG319
SG320
SG321
SG322
SG323
SG325
SG326
SG327
SG328
SG335
SG336
SG341
SG342
SG344
SG345
SG347
SG348
SG351
SG353
.SG359
SG139
SG38
Weight
0.40376
0.29470
0.40376
0.29470
0.08418
0.29470
0.40376
0.29470
0.29470
0.40376
0.40376
0.29470
0.29470
0.04080
0.29470
0.08418
0.04080
0.14992
0.29470
0.04080
0.40376
0.40376
0.04080
0.40376
0.04080
0.40376
0.29470
0.04080
0.40376
0.02665
0 02665
0.14992
0.40376
0.40376
0.29470
0.29470
0.02665
0.29470
0.02665
0.02665
0.02665
0.02665
0.29470
0.14992
0.29470
0.29470
0.40376
040376
0.40376
4 summer
summer
average
4CP
Customer NCP
August
summer
average
4CP
billing
average
coincidence
load factor Class NCP demand
coincidence energy
demand
demand
7.59
47.6%
3.61
30.2%
1738.575
45.8%
7.8575
3.595
59.1%
5.35
3.16
30.7%
1353.1
38.6%
6.03
2.3275
0.55
50.9%
0.28
30.9%
170.85
31.5%
0.755
0.2375
18.19
78.4%
14.26
31.1%
43.1% 7635.475
33.5275
14.46
69.2%
131.47
90.94
31.7%
72.5% 29809.125
128.395
93.0975
2.36
86.0%
2.03
31.9%
1566.125
32.5%
6.7
2.1775
11.26
85.2%
9.59
32.0%
2563.125
69.5%
10.955
7.6125
24.64
81.4%
20.06
33.2%
5692.55
81.1%
23.4325
18.995
24.31
78.1%
18.98
33.7%
85.9% 5630.175
22.85
19.6225
54.7%
7 13
3.9
34.1%
1974.825
51.8%
7.9025
4.09
42.7%
10.56
4.51
34.6%
3465.75
62.3%
13.665
8.5175
10.56
42.7%
4.51
34.6%
10.6% 4326.675
11.7575
1.2425
42.7%
10.56
4.51
34.6%
79.4% 6340.775
20.3925
16.185
10.56
42.7%
4.51
34.6%
1256.75
18.6%
24.19
4.4875
42.7%
10.56
451
34.6%
4008.1
87.5%
11.0025
9.6225
42.7%
10.56
4.51
34.6%
51.1% 22304.325
59.135
30.19
10.56
42.7%
4.51
34.6%
88.4% 79986.375
138.0825
122.085
42.7%
10.56
4.51
34.6%
19747.85
92.5%
48.9525
45.28
10.56
42.7%
4.51
34.6%
5039.25
74.3%
24.765
18.395
42.7%
10.56
4.51
34.6%
76.9% 90822.15
173.735
133 64
42.7%
10.56
4.51
34.6%
2212.175
27.7%
26.3725
7.2975
42.7%
10.56
4.51
34.6%
354.6
2.9%
17.405
0.51
42.7%
10.56
4.51
34.6%
1824.575
12.5%
24.255
3.0375
42.7%
10.56
4.51
34.6%
1837.7
17.4%
25.2425
4.3925
42.7%
10.56
4.51
34.6%
63600.3
78.0%
179.045
139.6125
42.7%
10.56
4.51
34.6%
1538.8
64.9%
6.0975
3.955
10.56
42.7%
4.51
34 6%
86.9% 4620.075
14.645
12.725
42.7%
10.56
4.51
34.6%
23281.75
68.6%
59.21
40.6275
42.7%
10.56
4.51
34.6%
4613.75
47.4%
19.1775
9.0825
42.7%
10.56
4.51
34.6%
82.1% 116194.38
211.005
173.205
42.7%
10.56
4.51
34.6%
260212
98.0%
426.2075
417.8275
42.7%
10.56
4.51
34.6%
17579.55
74.3%
74.32
100.0025
42.7%
10.56
4.51
34.6%
3883.25
71.5%
13.8075
9.8725
10.56
427%
4.51
34.6%
1050.225
0.6%
4.3825
0.0275
42.7%
10.56
4.51
34.6%
6592.15
94.9%
12.36
11.725
42.7%
10.56
4.51
34.6%
5112.05
47.3%
17.61
8.335
42.7%
10.56
4.51
34.6%
14568.65
55.2%
55.44
30.6
42.7%
10.56
4.51
34.6%
4921.35
96.7%
17.875
17.2825
42.7%
10.56
4.51
34.6%
121475.25
95.1%
229.4625
218.1225
42.7%
10.56
4.51
34.6%
95.3% 136469.75
256.1575
244.0625
42.7%
10.56
4.51
34.6%
92.2% 249127.68
478.4375
441.015
42.7%
10.56
4.51
34.6%
167708.8
88.8%
279.9025
248.685
42.7%
10.56
4.51
34.6%
674.2
4.8%
6.3
0.3025
42.7%
10.56
4.51
34.6%
10741.65
77.8%
19.4975
15.165
42.7%
10.56
4.51
34.6%
85.2% 5516.775
13.2175
11.2675
42.7%
10.56
4.51
34.6%
5603.6
47.3%
18.0725
8.555
42.7%
10.56
4.51
34.6%
5041.725
86.7%
20.3825
17.665
74.5%
17
12.67
350%
4030.95
75.3%
15.7125
11.8325
95.2%
4.95
4.71
35.5%
1271.95
84.0%
4.895
4 1125
29
Southwestern Public Service CompanySummary Data for Secondary General
Load Research Sample Data
OPUC Calcs
OPUC 7-2 values for analysis
Exhibit SPS-OPUC 7-2(V)(CD)
Page 3 of 4
Docket No. 43695
summary data for SG collected
CustID
SG170
SG67
SG144
SG167
SG21
SG268
SG149
SG165
SG59
SG263
SG215
SG73
SG186
SG275
SG37
SG155
SG7
SG253
SG28
SG210
SG201
SG163
SG93
SG265
SG89
SGI
SG129
SG122
SG187
SG282
SG198
SG83
SG82
SG45
SG27
SG77
SG224
SG79
SG239
SG80
SG236
SG242
SG6
SG231
SG241
SG50
SG68
SG56
SG266
Weight
0.29470
0.29470
0.29470
0.02665
0,40376
0.40376
0.14992
0.14992
0.40376
0.04080
0.40376
0.04080
0.40376
0.40376
0.29470
0.29470
0.29470
0.29470
0.29470
0.29470
0.29470
0.29470
0.29470
0.02665
0.29470
0.29470
0.08418
0.14992
0.29470
0.29470
0.04080
0.08418
0.29470
0.29470
0.08418
0.02665
0.29470
0.40376
0.08418
0.29470
0.08418
0.29470
0.04080
0.14992
0.40376
008418
0.40376
0.14992
0.02665
4CP
average
demand
13.87
16.1075
14.6625
99.96
10.7925
13.5925
0
31.75
6.12
172.44
6.9575
161.37
9.88
9.1625
7.56
15.635
10.245
14.94
7.895
14.1425
12.445
14.4225
12.94
112.185
6.21
13.045
58.475
45.7525
2.7675
12.01
80.3275
51.655
7.58
7.1525
63.15
250.39
4.8875
9.33
87.4825
10.0775
69.505
14.19
8 955
33.7475
7.94
71.835
9 255
13.89
366.3225
4 summer
average
summer
billing
4CP
average
summer
August
Customer NCP
demand
coincidence energy
load factor Class NCP demand
coincidence
17.445
79.5%
4533 25
35.5%
12.65
18.51
68.3%
16.745
96.2%
4371.8
35.7%
16.1
16.18
99.5%
26.135
56.1% 7150.775
37.4%
13.75
22.82
60.3%
467.46
21.4%
128793
37.6%
127.92
467.52
27.4%
12.28
87.9%
3384.7
37.7%
11.76
11.93
98.6%
15.07
90.2% 4156.775
37.7%
14.88
14.99
99.3%
13.5475
0.0% 3806.275
38.4%
0
0
#DIV/0!
39.6325
80.1%
11152.7
38.4%
29.74
40.03
74.3%
13.68
44.7% 3860.125
38.5%
10.08
12.96
77.8%
195.885
88.0% 55655.85
38.8%
147.06
204.57
71.9%
8.89
78.3%
2528.65
38.9%
7.66
8.39
91.3%
263.07
61.3% 76212.35
39.6%
237.96
266.4
89.3%
15 3625
64.3%
4548.45
40.4%
9.95
17.01
58.5%
13.37
68.5% 3985.075
40.7%
12.41
13.88
89.4%
9.6425
78.4%
2998.25
42.5%
6.62
7.2
91.9%
17.97
87.0%
5588.85
42.5%
16.95
19.44
87.2%
16.1575
63.4% 5229.875
44.2%
12.37
15.72
78.7%
19.0925
78.3%
6207.9
44.4%
15.74
20.26
77,7%
11.29
69.9% 3707.275
44.9%
7.67
12.23
62.7%
19.195
73.7%
6375.75
45.4%
15.81
20.15
78.5%
13.0175
95.6% 4385.075
46.0%
12.56
12.9
97.4%
16.5925
86.9%
5634.7
46.4%
13.01
20.46
63.6%
22.115
58.5%
7561.3
46.7%
24.93
19
76.2%
190.4175
58.9% 65632.85
47.1%
209.93
252 58
83 1%
7.525
82.5% 2641.175
47.9%
6.72
7.96
84.4%
14 7775
88.3% 5262.425 0.4864899
12.31
15.26
80.7%
73.845
79.2% 26623.25
49.3%
55.08
78.27
70.4%
69.6075
65.7% 25813.55
50.7%
92.5
93.8
98.6%
11.8225
23.4% 4386.775
50.7%
3.31
10.22
32.4%
12.5875
95.4% 4719.575
51.2%
11.92
12.84
92.8%
122.2425
65.7% 45869.725
51.3%
109.76
119.61
91.8%
70.3425
73.4%
26903.7
52.2%
67.73
70.48
96.1%
9.69
78.2% 3772.325
53.2%
6.17
8.17
75.5%
10.3225
69.3%
4023.75
53.3%
8.09
10.38
77,9%
72.39
87.2% 28222.65
53.3%
55.68
72.96
76.3%
266.6925
93.9% 104732.68
53.6%
263.99
276.75
95.4%
9.7675
50.0%
3874.95
54.2%
9.42
9.58
98.3%
12.1025
77.1% 4823.125
54.4%
9.34
11.92
78.4%
112.175
78.0% 45711.025
55.7%
85.86
118.49
72.5%
13.8225
72.9% 5706.125
56.4%
10.41
13 99
74.4%
95 5675
72.7% 39561.425
56.6%
92.68
94.77
97.8%
14.5925
97.2%
6042.1
56.6%
29.14
29.44
99.0%
24.54
36.5%
10325.5
57.5%
23.94
29.88
80.1%
34.84
96.9%
14731.55
57.8%
36.02
36.02
100.0%
8 015
99.1% 3395.525
57.9%
15.87
16 02
99.1%
73.21
98.1%
31050.7
57.9%
74.61
76.88
97.0%
10.59
87.4%
4508.2
58.2%
8.65
10.92
79.2%
24.5325
56.6%
10462
58.3%
14.6
24.29
60.1%
373.3875
98.1% 162138.88
59.3%
376.65
397.62
94.7%
30
Southwestern Public Service CompanySummary Data for Secondary General
OPUC Calcs
Load Research Sample Data
Exhibit SPS-OPUC 7-2(V)(CD)
Page 4 of 4
Docket No. 43695
OPUC 7-2 values for analysis
summary data for SG collected
CustID
SG109
SGI19
SG191
SG64
SG87
SG247
SG260
SG179
SG35
SG30
SG189
SG270
SG278
SG262
SG151
SG78
SG182
SG23
SG153
SG39
SG118
SG143
SG133
SG286
SG281
SG130
SG249
SG248
SG218
SG171
SG173
SG146
SG290
SG29
SG10
Weight
0.14992
0.29470
0.29470
0.04080
0.40376
0.14992
0.02665
0.29470
0 08418
0.29470
0.40376
0.40376
0.04080
0.04080
0.02665
0.02665
0.02665
0.29470
0.02665
0.02665
0.04080
0.08418
0.02665
0.02665
0.02665
0.08418
0.02665
0.04080
0.08418
0.02665
0.08418
0.02665
014992
0.04080
0.04080
4 summer
summer
average
4CP
Customer NCP
August
summer
average
4CP
billing
average
coincidence
factor
Class
NCP
demand
load
coincidence energy
demand
demand
20.52
100.0%
20.52
60.2%
9096.725
88.9%
20.655
18.36
86.6%
15.84
13.72
61.3%
6912.9
87.7%
15.4175
13.52
32.96
95.5%
31.48
62.1%
11328.25
94.3%
24.94
23.52
149.11
93.9%
139.97
62.1%
91.3% 65090.375
143.0825
130.5725
22.44
96.5%
21.65
62.3%
6246.125
79.5%
13.7075
10.8925
99.1%
44.12
44,52
63.9%
72.4% 20516.725
43.8325
31.72
384.84
98.5%
378.9
65.0%
183425.4
94.9%
385 47
365.67
12.67
88.6%
11.23
66.1%
5688.625
90.2%
11.755
10.6
85.37
79.3%
67.72
66.4%
79.9% 40327.175
82.9325
66.29
47.1%
11.78
5.55
66.9%
5206.85
56.4%
10.6325
5.995
0.62
24.2%
0.15
67.6%
255
32.0%
0.515
0.165
424.13
78.7%
333.9
68.4%
142824.68
80.7%
285.385
230.2075
222.14
94.7%
210.33
68.9%
107621.4
95.8%
213.4025
204.375
128.03
99.8%
127.8
69.0%
93.8% 59921.925
118.6325
111.3225
76.4%
268.38
205.02
70.2%
132026.83
80.7%
257.04
207.4725
229.05
93.7%
214.65
70.5%
114318.58
94.2%
221.4
208.4925
89.3%
246.64
220.32
71.3%
95.3% 125181.05
239.8625
228.625
8.26
78.9%
6,52
72.4%
4318.1
86.0%
8.15
7.0125
207
77.2%
159.84
73.0%
110609.93
67.6%
206.955
139.9275
244.49
74.5%
182.12
73.4%
69.8% 129874.68
241.8675
168.7975
81.41
94.5%
76.95
73.4%
89.9% 44656.45
83.11
74.7075
51.62
99.2%
5123
74.0%
95.2% 29440.55
54.3225
51.74
371.34
93 0%
345.42
74.6%
195357.63
94
1%
357.615
336.5775
254.45
55.9%
142.2
75.6%
64.9% 139714.18
252.505
163.9075
72.4%
209.92
151.92
75.6%
111108.9
70.9%
200.7575
142.28
78.7%
38.47
30.27
75.8%
21170.725
83.5%
38.15
31.87
207.54
80.7%
167.4
77.1%
122586.1
77.8%
217.26
169.0425
73.9°/a
100.22
74.02
78.0%
55950
79.9%
97.99
78.285
42.44
87.7%
37.21
78.2%
23336.3
84.9%
40.7875
34.64
334.08
98.2%
328.14
82.5%
214893.55
94.9%
355.995
337.815
47.2
89.0%
42.01
82.8%
29625.6
87.6%
48.855
42.8
219.31
86.8%
190.28
83.0%
134998.6
88.9%
222.23
197.6575
96.2%
16.71
16.08
83.8%
10445.1
95.8%
17.0375
16.32
132.19
964%
127.49
85.2%
97,0% 85805.525
137.5775
133.5
100.44
97.7%
98.15
90.3%
98 3% 66328 85
100.2975
98.62
31
Southwestern Public Service Co^npotWy Data for Secondary General
Load Research Sample Data
OPUC Calcs
OPUC 7-2 values for analysis
Summer
load
Factor
<10%
10-20%
20-30%
30-40%
40-60%
>60%
4CP
average
demand
2.40
10.39
15.69
15.87
17.15
59.93
4 summer
average
maximum
demand
22.48
30.59
26.73
23.73
22.16
71.40
4CP
coincidence
10.7%
34.0%
58.7%
66.9%
77.4%
83.9%
August
Customer
August
maximum
Class NCP demand
1.47
15.32
10.68
29.50
17.54
27.13
8.71
14.23
20.45
24.30
72.49
86.78
Exhibit SPS-OPUC 7-2(V)(CD)
Page 1 of 1
Docket No. 43695
NCP
coincidence
9.6%
36.2%
64:6%
61.2%
84.2%
83.5%
summer
average
energy
663
3,466
5,012
7,365
8,297
36,953
summer
load
factor
4.0%
15.5%
25.6%
42.4%
51.2%
70.7%
32
Rule of 80 Workpapers
Large Municipal and School
Page 1 of 2
OPUC 7-2 LMS Summary Data
summary data for LMS collected - all 4 summer months, at least 9 month s annual data
4 summer
summer
average
4CP
Weight
CustfD
summer
average
4CP
average maximum
energy
load factor
demand coincidence
demand
LMS Table
Summer
load
Factor
4CP
average
demand
4 summer
average
maximum
demand
4CP
coincidence
summer
average
energy
summer
summer 4CP load
factor
load factor
LMSTX151
0.25000
1,80
20906
0,9%
10,629
6.9%
<10%
5.24
70.61
74%
4,083.97
7.9%
106.6%
LMSTX121
0.25000
0.76
41.16
1.9%
2,473
8.2%
10-209/6
9.96
49.18
20.2%
5,287,67
147%
72.6%
0.69942
5.43
28 70
18.9%
1,853
8.8%
20-30%
10 17
35.12
28.9%
6,684.48
26.0%
89,8%
9.3%
30-40%
37.98
42.3%
9,965.41
35.8%
45.51
60.9%
16,465,82
49.4%
84,8%
81.1%
33.90
75.5%
18,127.67
73.1%
96.7%
LMSTX66
LMSTX121
0.25000
12.61
78.89
16.0%
5,392
LMSTX140
0.69942
13.84
28,54
48.5%
2,233
10.7%
40-60%
1606
27.72
LMSTX112
069942
9.28
24.66
37.6%
2,052
11.4%
>60%
25.60
74.87
1.0%
42.9%
6,293
11.5%
7,107
11.9%
0.0%
4,385
0.0%
13,214
12.4%
12.9%
LMSTX154
0.69942
0.75
LMSTXI
0,69942
35.00
81.58
LMSTX82
0.25000
-
48.40
LMSTX64
5.23
139.55
LMSTX2
025000
0 69942
56.52
9.2%
5,716
LMSTX104
0.69942
12.82
51.47
249%
6,585
13.8%
17.5%
LMSTX137
LMSTX54
0.69942
14.71
47.19
312%
6,156
178%
0.69942
1.73
1171
14.7%
1,651
19.3%
LMSTX103
0.69942
9,54
54 67
17.4%
7,793
19.5%
LMSTX153
0.25000
13.86
73.38
18.9%
10,549
19.6%
LMSTX117
0.69942
2.40
19.97
12.0%
2,899
198%
20.2%
'
LMSTX93
LMSTX57
0.25000
069942
22.90
15.52
140.03
58.41
16,4%
26.6%
20,696
8,933
20.9%
LMSTX34
0.69942
0.23
15.96
0.69942
19.67
LMSTX158
0.69942
4.56
406
2,714
3,445
23.2%
LMSTX141
1.5%
23.2%
16.64
24,4%
3,007
24.7%
LMSTX145
LMSTX123
LMSTXI19
0.69942
7.48
52.48
21.64
56.4%
76.1%
6.2%
1,378
9,718
4,067
LMSTXI6
0,69942
4.22
3994
1.34
7.45
27 6%
5,276
LMSTX155
0.69942
13.45
26,96
37.31
25.2%
25,3%
257%
26,7%
7,358
26.9%
LMSTXI 1
0.69942
15.54
41,43
36.1%
37.5%
8,206
271%
LMSTX65
0.69942
0.08
69.16
0.69942
35.47
LMSTX118
0,69942
0.25000
0.69942
5.61
16.56
13,732
7,098
27.1%
LMSTX84
0.1%
15.8%
13,420
28,0%
57,78
9.02
91.18
19.20
25.3%
63.4%
47.0%
18,705
3,950
28.0%
28,1%
3.44
6.66
19,09
13.70
29.43
LMSTX144
LMSTX23
LMSTX75
LMSTX131
025000
0.69942
0.69942
LMSTX56
0.69942
0.25000
LMSTX113
0.69942
LMSTX148
0.69942
0.25000
LMSTX59
LMSTX3
LMSTX135
LMSTX36
LMSTX48
LMSTX129
LMSTX43
LMSTX133
LMSTX91
LMSTX76
LMSTX37
0,69942
0.69942
65,43
23.9%
27.3%
18,0%
4,058
29.0%
57,08
48.6%
51.6%
2,917
12,336
29.1%
29.5%
15.83
440
22.86
69.2%
4,983
29 8%
13,91
3,079
30.2%
18.44
157.73
14.36
31.6%
11 7%
35,601
30.8%
7.83
84.8%
61.4%
3,359
1,854
32,01/6
32.3%
12.17
4.81
069942
0.25000
22 62
35,41
63.9%
8,433
32.5%
78.75
33 6%
9.92
11.52
9.43
1750
18.09
58.7%
20.3%
658%
52.1%
32,998
069942
0.69942
0,69942
0.69942
134 16
48 78
12,021
4,508
4,711
12,58
49.73
25,3%
13,123
33.7%
35.2%
356%
36,1%
025000
0.69942
119,11
165.54
71.9%
45,074
13,52
39.73
34.0%
10,851
LMSTX157
LMSTX60
0.25000
13,31
118.72
11.2%
32,516
0,25000
LMSTX92
LMSTX45
LMSTX127
0,69942
0.69942
0.69942
62.25
10.63
7.69
3,14
111.56
14.79
34,82
16.70
558%
719%
22.1%
18.8%
31,000
4,151
9,773
4,735
LMSTX125
0.69942
6.09
3,930
0.25000
37,04
13 78
117,65
44.2%
LMSTX114
31.5%
LMSTX136
0.69942
17,73
23.60
LMSTX81
0,69942
11.47
14,22
75,1%
80.6%
33,730
6,781
LMSTX47
LMSTX4I
069942
0.25000
9.02
30.20
12 09
66.65
746%
45.3%
LMSTX62
0,25000
LMSTX120
0,25000
15.82
76.01
LMSTXI42
0.69942
LMSTX85
LMSTX4
LMSTX97
LMSTX128
0.04191
0.69942
0.69942
LMSTX139
0 69942
60.61
14.53
LMSTX21
0.25000
LMSTXIO
0.25000
0.25000
37.2%
37.3%
374%
38,0%
38.3%
38.3%
387%
39.0%
39.2%
39,2%
4,155
39.9%
3,536
40.0%
40.3%
19,682
8,724
44,349
40.6%
5,550
412%
73,262
5,679
10,751
17 63
240%
802%
725%
860%
82.4%
23,044
5,829
41.6%
432%
432%
44.7%
45.2%
48.55
60,31
80.5%
20,500
46,4%
69.40
136,87
50.7%
47,350
47.3%
11.88
57.77
14,41
24.63
29.36
53.9%
149,05
18.39
51.0%
64.6%
24030
17,96
33.97
70.49
1
406%
33
OPUC 7-2 LMS Summary Data
Rule of 80 Workpapers
Large Municipal and School
Page 2 of 2
LMSTX7
0.25000
87.49
267.49
32.7%
95,071
48.6%
LMSTX50
0.04191
11.16
24.48
45.6%
8,724
48.7%
LMSTX23
0.69942
13.94
38.14
36.6%
13,635
LMSTX52
0.25000
109.40
148.74
54,192
48.8%
49.8%
LMSTXI7
0.25000
23.72
35.05
736%
67.7%
12,799
499%
LMSTX7
LMSTX109
LMSTX19
0.25000
0.25000
0.69942
20.25
32.85
9.39
60.99
44.74
1350
33.2%
73.4%
69.5%
22,648
16,759
5,117
5075/6
51.2%
51.8%
LMSTXI26
0.69942
0.69942
5.68
968
58.6%
3,718
52.5%
LMSTX145
1017
13.47
5,251
LMSTX106
0,25000
40.26
80.03
755%
50.3%
31,385
53.3%
53.6%
LMSTX152
0.25000
19.74
32 23
613%
12,883
54.6%
LMSTX89
0.25000
59.05
87.39
67.6%
35,484
55 5"/0
LMSTX108
0.69942
17.79
20.09
885%
8,213
55.8%
LMSTX21
0.25000
33 10
52.97
22,109
36,473
57.0%
LMSTX68
0.25000
64.06
86.08
62.5%
74.4%
LMSTX58
0.25000
33.84
48.02
705%
20,593
58,6%
LMSTX49
0.04191
235 52
242.89
97.0%
105,069
59.1%
LMSTX33
0.25000
90.60
59.5%
0.69942
11.64
79.0%
79.6%
49,885
LMSTX72
114.63
14.62
6,392
59.7%
LMSTX124
LMSTX134
LMSTXI32
0.04191
0.25000
0.04191
10109
7.62
135.47
70.2%
32.7%
596%
63,981
10,499
102,668
60.7%
616%
61.7%
LMSTX42
025000
77.18
144.02
2328
22734
79.84
96.7%
36,761
LMSTX26
0.25000
48.73
98.14
49.7%
45,385
629%
63.2%
LMSTXIOO
0.25000
44.40
51.91
85.5%
24,645
LMSTX35
069942
13.11
21.81
60.1%
10,854
64.9%
68.0%
LMSTX143
0.69942
11.73
1646
69.0%
0.69942
14.42
15.97
71.3%
90.3%
8,307
LMSTX130
8,809
75 4%
LMSTX44
004191
0.00867
60.33
76 1%
0,04191
0.25000
0 69942
0.69942
63.23
78.82
783%
947%
80.2%
42,940
386.80
77 08
408.48
228,374
46,767
76.4%
81.1%
64.80
8.47
19.33
65.62
12.78
21.01
98 8%
66.3%
92.0%
42,374
8,684
15,690
88.2%
92.9%
102.0%
LMSTX156
LMSTX12
LMSTX67
LMSTX20
LMSTX32
57.9%
34
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45
MADISON GAS AND ELECTRIC COMPANY
"Standard" Embedded Cost of Service Study, 3270-UR-120
Total
Electric
ti't ,
Total
General
Services
Total
Business
Services
3,520,448
12,211,621
97,819,547
1,402,110
4,863,596
38,959,183
2,118,338
7,348,025
58,860,364
113,551,616
45,224,890
68,326,727
7,146,260
21,448,581
4,930,439
14,798,080
6,964,433
5,443,998
4,805,087
5,189,217
181,827
16,004,583
125,353
9,608,863
48,323,361
22,402,735
25,920,626
2,734,014
25,826,152
1,886,286
17,818,309
48, 264, 761
2,664,451
6,555,097
1,838,329
6,248,315
17, 306,191
69,563
19,271,055
47,957
11,569,994
30, 958, 570
96,588,122
39,708,926
56,879,196
Total
Electric
Utilit
Total
General
Services
Total
Business
Services
5,528,558
73,450,849
78,979,407
352,646
48,728,578
49,081,224
5,175,912
24,722,271
29,898,183
8,965,437
119,112,234
128,077.671
571,872
79,021,139
79,593,011
8,393,565
40,091,094
48,484,660
207,057,078
128,674,235
78,382,843
4,762,038
61,252,068
1,278,857
218,805
67,511,767
4,636,188
18,604,983
509,338
87,145
23,837,653
125,850
42,647,085
769,519
131,660
43,674,114
43,435,325
27,430,268
31.549,274
21,713,147
11,886,051
5,717,121
5,247,215
5,735,522
488,308
3,102,755
3,102,755
564,412,454
294,299,188
270,113,266
0 (PRIMARY DISTRIBUTION DEMAND) ALLOCATOR
46
Line
No
Texas Retail
AVERAGE AND EXCESS CALCULATION
FOR THE TEST PERIOD ENDED: JUNE 30, 2014
Total
Texas
I
Hours in Year
2
3
4
5
6
4-CP Production
Average
Excess
Sys Excess
AED4-CP
Residential
RTX
Residential
RHTX
Sum of4-CP Check
Sum of Average Check
Sum of Sys. Excess check
Area
Lighting
Street
Lighting
Small School
Small Mumicipal
Service
Small
General
Service
Large
Municipal
[Secondary]
8,760
2,367,380
1,727,087
644,316
640,293
2,367,380
497,293
212,331
284,962
283,183
520,077
183,591
98,201
85,389
84,856
188,878
0
4,355
0
0
4,161
0
3,275
0
0
3,129
55,233
34,992
20,241
20,115
55,964
2,800
2,333
468
465
2,750
26,559
20,095
6,464
6,423
26,396
2,367,380
2,367,380
1,727,087
640,293
495,514
(22,784)
183,057
(5,287)
4,355
(4,161)
3,275
(3,129)
55,106
(732)
2,798
51
26,519
164
8 57%
13,40%
3.96%
4.01%
0 18%
0001/6
0.13%
0 00%
1 41%
095%
009%
0.02%
0.81%
0.30"/0
21.97%
798%
0 19%
0 13%
236%
012%
1.11%
7
8
9
10
Exhibit SPS-TTEC 2-13(a)
Page I of 2
Docket No, 43695
2-13 (a) 4CP
Southwestern Public Service Company
Adjusted Base Period, Adjusted for Weather, Retail, and Wholesale Adjmnt
Average allocation
Excess allocation
Total allocation
sum res small GS =>
3231%
11
12
13
14
4-CP Transmission
Average
Excess
Sys Excess
2,380,134
1,727,087
657,104
653,047
505,509
212,331
293,178
291,368
186,480
98,201
88,279
87,734
0
4,355
0
0
0
3,275
0
0
56,281
34,992
21,290
21,158
2,843
2,333
510
507
26,951
20,095
6,855
6,813
15
AED 4-CP
2,380,134
538,178
194,201
4,086
3,072
57,445
2,778
26,780
16
17
18
19
Sum of4-CP Check
Sum of Average Check
Sum of Sys. Excess check
2,376,561
2,380,134
1,727,087
653,047
8.37%
3 87%
0 17%
0.13%
138%
009%
079%
Excess allocation
14 24%
429%
000%
000"/e
1.03%
002%
0.33%
Total allocation
22.61%
33 18%
8 16%
0.17%
0 13%
241%
012%
1 13%
Average allocation
sum res small GS =>
PROD
System
4CP
4 CP (MW)
System load MWh
System load factor
4,513
27,558,186
69 70%
TRANS
System
4CP
5,383
32,106,001
68 08%
47