2013 Transmission Stakeholder Meeting
Ameren Transmission Company of Illinois and
Ameren Illinois Company
October 17, 2012
AGENDA
Main Purpose is to review ATXI and AIC Projected 2013 Transmission
Rate Calculations
•
•
•
•
•
•
•
Background on Attachment O, GG & MM
Overview of MTEP and MVPs
Forward Looking Rates
Approved Incentives
ATXI Comparison to Current Revenue Requirement
AIC Comparison to Current Revenue Requirement
2013 AMIL Pricing Zone NITS Charge
2
AIC AND ATXI
• Both AIC and ATXI are transmission owning subsidiaries of Ameren
Corporation, as well as MISO Transmission Owners (TOs)
• The sum of their Attachment O net revenue requirements equals the
total revenue requirement for AMIL pricing zone to be collected
under Schedule 9 (NITS)
• AIC will continue to build and own traditional reliability projects
• ATXI is in the process of building and will own new regional
transmission projects
3
MISO ATTACHMENTS O, GG & MM
Calculate rates for Schedules 9, 26 & 26-A
•
•
•
•
•
Attachment GG - Schedule 26 (page 5)
Attachment MM - Schedule 26-A (page 6)
Attachment O - net revenue requirement billed under Schedule 9 (page 7)
Schedules 26 and 26-A are billed by MISO
Schedule 9 is billed by Ameren
4
MISO ATTACHMENT GG
• Cost Recovery for certain Network Upgrades
• Eligible projects
• Baseline Reliability
• Market Efficiency
• Generator Interconnections
• Cost shared based upon project type
• MISO-wide based on load
• Subregional based on LODF (Line Outage Distribution Factor)
• AIC has three Attachment GG projects completed
• ATXI has no Attachment GG projects
5
MISO ATTACHMENT MM
• Cost recovery for Multi-Value Projects (MVPs)
• Very similar format as Attachment GG
• Criteria for being considered
• Developed through planning process and support energy policy
• Multiple types of economic value across multiple pricing zones with
benefit to costs > 1
• Address at least one:
• Projected NERC violation
• Economic-based issue
• Cost shared across MISO based on load
• AMIL Zone is approximately 9%
• Ameren MVPs will primarily be built by ATXI
• AIC will be responsible for modifications needed to its existing facilities
6
MISO ATTACHMENT O, GG & MM
• All transmission costs included in Attachment O calculation
• Schedule 9 based on net revenue requirement – reductions for:
•
•
•
•
Costs recovered in Schedules 26 & 26-A
Point-to-Point revenue in Schedules 7 & 8
Rental revenue
Revenue from generator interconnections
• Questions on Tariffs?
7
MISO TRANSMISSION EXPANSION PLAN (MTEP)
• Developed on an annual basis building upon previous analysis
•
•
MISO, Transmission Owners & Stakeholders
Includes subregional planning meetings
• MTEP goals
•
•
•
•
•
•
•
Ensure the reliability of the transmission system
Ensure compliance with NERC Standards
Provide economic benefits, such as increased market efficiency
Facilitate public policy objectives, such as meeting Renewable Portfolio
Standards
Address other issues or goals identified through the stakeholder process
Multiple future scenarios analyzed
End result – comprehensive, cohesive plan for MISO footprint
• MTEP approved by MISO Board of Directors
8
MISO MVPS
• Brief history of development
• Began investigating value added expansion in 2003
• 2008 Regional Generation Outlet Study (RGOS) - formed basis of
Candidate MVP portfolio
• Portfolio refined due to additional analysis
• MISO approved portfolio of 17 Projects
• Seven transmission line segments (MTEP proj numbers) in Ameren territory
• Ameren identifies these three projects as:
• Illinois Rivers (four line segments)
• Spoon River
• Mark Twain (two line segments)
• Broadly cost-shared, AMIL pricing zone allocated 9% of each MVP
no matter where project is located or who builds it
9
MAP OF AMEREN MVPS
10
FORWARD LOOKING RATES
• Rates better reflect current costs
• Implemented by several MISO TOs
• Requires true-up to actual year costs
•
•
•
•
New calculations based on projected 2013 data
Rate base items -13 month average balance
Interest on over/under recovery
2013 true-up calculated in 2014 and reflected in 2015 rates
• FERC approved forward looking rates for ATXI effective March 1,
2012
• AIC filed request at FERC in July 2012 and expects an Order by the
end of 2012.
11
FORWARD LOOKING RATES TIMELINE
• September 1, 2012
• Calculate 2013 revenue requirements for AIC & ATXI
• October 31, 2012
• Meet with Customers to discuss rate input projections and cost detail
• January 1, 2013
• New rates in effect
• July 1, 2013
• Calculate and post 2012 true-up (Only ATXI in 2013)
• September 1, 2013
• Calculate 2014 revenue requirements for AIC & ATXI
• Includes 2012 true up with interest for ATXI
• October 31, 2013
• Meet with Customers to discuss rate input projections and cost detail
• January 1, 2014
• New rates in effect based on 2014 projections and 2012 true-up for ATXI
12
RATE INCENTIVES
• FERC approved the following rate incentives for Illinois River in
Docket No. EL10-80
– CWIP (no AFUDC)
– Abandonment (requires additional filing prior to recovery)
– Hypothetical capital structure during construction for ATXI
• July 2012 filing requested similar incentives for Spoon River and
Mark Twain Projects
13
ATXI Revenue Requirement
Projected 2012 vs Projected 2013
14
ATXI PROJECTIONS FOR 2013
ATXI Rate Base
Page.Line
2.6
2.12
2.18
Total Gross Plant
Total Accum Depreciation
TOTAL NET PLANT
2.18a
100% CWIP RECOVERY
2.20
2.21
2.22
2.25
2.26
2.27
2.28
ADJUSTMENTS TO RATE BASE
Account No. 282
Account No. 283
Account No. 190
Land Held for Future Use
CWC
Materials & Supplies
Prepayments
TOTAL ADJUSTMENTS
2.30
TOTAL RATE BASE
Mar-12
53,171,000
1,653,000
51,518,000
Jan-13
63,438,000
2,652,000
60,786,000
Change
10,267,000
999,000
9,268,000
Percent
19%
60%
18%
8,742,000
33,665,000
24,923,000
285%
-11,550,000
0
4,009,000
0
68,110
0
0
-7,472,891
-12,172,000
-8,000
3,984,000
0
115,500
0
0
-8,080,500
0
-622,000
-8,000
-25,000
0
47,391
0
0
-607,610
N/A
5%
N/A
-1%
N/A
70%
N/A
N/A
8%
52,787,110
86,370,500
33,583,391
64%
15
ATXI PROJECTIONS FOR 2013
ATXI Expenses
Mar-12
Page.Line
3.1
3.1a
3.2
3.3
3.4
3.5
3.5a
3.8
O&M
Transmission
Less LSE Expenses
Less Account 565
A&G
Less FERC Annual Fees
Less EPRI, ect.
Plus Trans. Reg. Comm. Exp
TOTAL O&M
3.12
TOTAL DEPRECIATION
3.13
3.16
3.18
3.27
TAXES
Payroll
Property
Other
Income Taxes
TOTAL TAXES
TOTAL EXPENSES
Jan-13
Change
Percent
44,876
0
0
500,000
0
0
0
544,876
41,000
0
0
883,000
0
0
0
924,000
-3,876
0
0
383,000
0
0
0
379,124
-9%
N/A
N/A
77%
N/A
N/A
N/A
70%
1,013,856
1,006,000
-7,856
-1%
0
0
0
2,391,316
2,391,316
0
0
25,000
4,188,901
4,213,901
0
0
0
25,000
1,797,584
1,822,584
N/A
N/A
N/A
N/A
75%
76%
3,950,048
6,143,901
2,193,852
56%
16
ATXI PROJECTIONS FOR 2013
ATXI True-up & Net Revenue Requirement
Page.Line
1.1
1.6
Gross Revenue Requirement
Total Revenue Credits
1.6a
1.6b
1.6c
1.6d
1.6e
Historic Year Actual ATRR
Projected ATRR from Prior Year
Prior Year ATRR True-Up
Prior Year Divisor True-Up
Interest on Prior Year True-Up
1.7
NET REVENUE REQUIREMENT
Mar-12
7,790,601
611,000
Jan-13
7,845,158
488,000
Change
54,557
-123,000
Percent
1%
-20%
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
N/A
N/A
N/A
N/A
N/A
7,179,601
7,357,158
177,557
2%
17
ATXI PROJECTIONS FOR 2013
ATXI Attachment MM Calculation - Page 1
(1)
Line No.
1
1a
2
Gross Transmission Plant - Total
Transmission Accumulated Depreciation
Net Transmission Plant - Total
3
3a
3b
3c
3d
O&M TRANSMISSION EXPENSE
Total O&M Allocated to Transmission
Transmission O&M
Less: LSE Expenses included in above, if any
Less: Account 565 included in above, if any
Adjusted Transmission O&M
4
Annual Allocation Factor for Transmission O&M
4a
4b
OTHER O&M EXPENSE
Other O&M Allocated to Transmission
Annual Allocation Factor for Other O&M
(3)
(4)
Transmission
97,103,000
2,652,000
94,451,000
Allocator
924,000
41,000
41,000
1.55%
1.55%
883,000
0.91%
0.91%
5
6
GENERAL AND COMMON (G&C) DEPRECIATION
EXPENSE
Total G&C Depreciation Expense
Annual Allocation Factor for G&C Depreciation Expense
0.00%
0.00%
7
8
TAXES OTHER THAN INCOME TAXES
Total Other Taxes
Annual Allocation Factor for Other Taxes
25,000
0.03%
0.03%
9
Annual Allocation Factor for Other Expense
0.94%
0.94%
10
11
INCOME TAXES
Total Income Taxes
Annual Allocation Factor for Income Taxes
4,188,901
4.43%
4.43%
12
13
RETURN (Note I)
Return on Rate Base
Annual Allocation Factor for Return on Rate Base
7,336,763
7.77%
7.77%
14
Annual Allocation Factor for Return
15
HYPOTHETICAL CAPITAL STRUCTURE (HCS) RETURN
Annual Allocation Factor HCS Return (Note J)
12.20%
0.0042%
0.0042%
18
ATXI PROJECTIONS FOR 2013
ATXI Attachment MM Calculation - Page 2
(1)
Line No.
Project Name
Multi-Value Projects (MVP)
1a
Pana-Sugar Creek
1b
Sidney-Rising
1c
Palmyra-Pawnee
1d
Pawnee-Pana
Line No.
(2)
MTEP
Project
Number
2237
2239
3017
3169
(1)
(2)
Project Name
MTEP
Project
Number
(3)
Project Gross
Plant
(Note C)
2237
2239
3017
3169
$0
$0
$0
$0
(10)
(11)
Project Net
Plant
Annual
Allocation
Factor for
Return
$13,801,511
$3,083,519
$23,644,040
$2,363,032
(5)
(6)
(7)
(8)
(9)
Other
Annual
Expense
Annual
Project
Transmission
Allocation for
Annual
Allocation for
Annual
Accumulated
O&M Annual
Transmission
Allocation
Other
Expense
Depreciation Allocation Factor O&M Expense
Factor
Expense
Charge
Page 1 line 4
(Col 4 * Col 5) Page 1 line 9 (Col 3 * Col 7) (Col 6 + Col 8)
$13,801,511
$3,083,519
$23,644,040
$2,363,032
(Col 3 - Col 4)
Multi-Value Projects (MVP)
1a
Pana-Sugar Creek
1b
Sidney-Rising
1c
Palmyra-Pawnee
1d
Pawnee-Pana
(4)
1.55%
1.55%
1.55%
1.55%
$0
$0
$0
$0
(11a)
(12)
0.94%
0.94%
0.94%
0.94%
$129,056.49
$28,833.66
$221,092.95
$22,096.47
(13)
(14)
Annual
Project
Annual
Allocation Factor Annual Return Depreciation
Revenue
for HCS Return
Charge
Expense
Requirement
(Pg 1 line 15)
(Col 10 * (Col
(Sum Col. 9,
(Pg 1 line 14)
(Note J)
11 + Col 11a))
(Note E)
12 & 13)
12.20%
12.20%
12.20%
12.20%
0.0042%
0.0042%
0.0042%
0.0042%
$
$
$
$
1,684,753
376,406
2,886,233
288,456
$0
$0
$0
$0
$
$
$
$
$129,056.49
$28,833.66
$221,092.95
$22,096.47
(15)
(16)
True-Up
Adjustment
MVP Annual
Adjusted
Revenue
Requirement
Sum Col 14 & 15
(Note G)
(Note F)
1,813,810
405,239
3,107,326
310,552
$0
$0
$0
$0
$1,813,809.87
$405,239.48
$3,107,325.94
$310,552.28
$0
$5,636,928
2
MVP Total Annual Revenue Requirements
$5,636,928
3
Rev. Req. Adj For Attachment O
$5,636,928
19
ATXI PROJECTIONS FOR 2013
Ameren MVPS
Ameren Name
2012-2013 CAPEX MTEP #s
MTEP Description
Illinois Rivers
$78 million
2237
2239
3017
3169
Pana - Mt. Zion - Kansas - Sugar Creek 345 kV line
Sidney to Rising 345 kV line
Palmyra-Quincy-Meredosia - Ipava & Meredosia-Pawnee 345 kV Line
Pawnee to Pana - 345 kV Line
Spoon River
$0.0 million
3022
Fargo-Galesburg-Oak Grove 345 kV Line
Mark Twain
$0.0 million
2248
3170
Adair - Ottumwa 345
Adair-Palmyra 345 kV Line
20
AIC Revenue Requirement
June 2012 vs Projected 2013
21
AIC PROJECTIONS FOR 2013
AIC Rate Base
Page.Line
2.6
2.12
2.18
Total Gross Plant
Total Accum Depreciation
TOTAL NET PLANT
2.18a
100% CWIP RECOVERY
2.20
2.21
2.22
2.23
2.25
2.26
2.27
2.28
ADJUSTMENTS TO RATE BASE
Account No. 282
Account No. 283
Account No. 190
Account No. 255
Land Held for Future Use
CWC
Materials & Supplies
Prepayments
TOTAL ADJUSTMENTS
2.30
TOTAL RATE BASE
Jun-12
953,216,965
425,415,799
527,801,167
Jan-13
1,203,711,514
446,612,300
757,099,214
Change
250,494,549
21,196,502
229,298,047
Percent
26%
5%
43%
0
0
0
N/A
-136,971,095
-1,155,409
26,320,342
0
1,637,671
3,755,531
4,038,558
1,015,306
-101,359,096
-221,677,954
-10,630,339
47,632,202
-785,425
528,800
4,399,010
4,093,957
936,720
-175,503,029
0
-84,706,860
-9,474,930
21,311,860
-785,425
-1,108,871
643,479
55,399
-78,585
-74,143,933
N/A
62%
820%
81%
N/A
-68%
17%
1%
-8%
73%
426,442,071
581,596,185
155,154,114
36%
22
AIC PROJECTIONS FOR 2013
AIC Expenses
Jun-12
Page.Line
Jan-13
Change
Percent
3.1
3.1a
3.2
3.3
3.4
3.5
3.5a
3.8
O&M
Transmission
Less LSE Expenses
Less Account 565
A&G
Less FERC Annual Fees
Less EPRI, ect.
Plus Trans. Reg. Comm. Exp
TOTAL O&M
38,237,889
3,090,097
14,522,516
9,969,183
0
582,803
32,593
30,044,248
39,184,517
3,090,097
11,657,490
11,319,374
0
596,873
32,649
35,192,080
946,628
0
-2,865,027
1,350,191
0
14,070
56
5,147,832
2%
0%
-20%
14%
N/A
2%
0%
17%
3.12
TOTAL DEPRECIATION
17,308,466
22,079,756
4,771,291
28%
3.13
3.16
3.18
3.27
TAXES
Payroll
Property
Other
Income Taxes
TOTAL TAXES
642,493
802,435
241,057
21,427,193
23,113,179
875,947
1,005,911
369,141
26,615,064
28,866,063
0
233,453
203,475
128,085
5,187,871
5,752,884
N/A
36%
25%
53%
24%
25%
TOTAL EXPENSES
70,465,892
86,137,899
15,672,007
22%
23
AIC PROJECTIONS FOR 2013
Total AIC Revenue Requirement
2.30
4.30
3.28
TOTAL RATE BASE
Rate of Return
Return
Jun-12
426,442,071
10.44%
44,537,530
Jan-13
581,596,185
10.06%
58,531,643
Change
155,154,114
-0.38%
13,994,113
Percent
36%
-4%
31%
3.29
Total Expenses
TOTAL GROSS REV. REQ.
70,465,892
115,003,422
86,137,899
144,669,542
15,672,007
29,666,120
22%
26%
3.30
3.30a
3.31
Less ATT. GG Adjustment
Less ATT. MM Adjustment
GROSS REV. REQ. UNDER ATT. O
2,539,687
0
112,463,734
3,600,384
0
141,069,158
1,060,697
0
28,605,423
42%
N/A
25%
Page.Line
24
AIC PROJECTIONS FOR 2013
AIC True-up & Net Revenue Requirement
Page.Line
1.1
1.6
Gross Revenue Requirement
Total Revenue Credits
1.6a
1.6b
1.6c
1.6d
1.6e
Historic Year Actual ATRR
Projected ATRR from Prior Year
Prior Year ATRR True-Up
Prior Year Divisor True-Up
Interest on Prior Year True-Up
1.7a
1.7b
1.7
NET REVENUE REQUIREMENT
Prairie Power
AIC Adjusted Revenue Requirement
Jun-12
112,463,734
7,886,618
Jan-13
141,069,158
8,011,058
Change
28,605,423
124,440
Percent
25%
2%
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
N/A
N/A
N/A
N/A
N/A
104,577,116
583,724
105,160,840
133,058,099
583,724
133,641,823
28,480,983
0
28,480,984
27%
0%
27%
25
AIC PROJECTIONS FOR 2013
AIC Attachment GG Calculation - Page 1
(1)
Line
No.
1
Gross Transmission Plant - Total
2
Net Transmission Plant - Total
(2)
Attachment O
Page, Line, Col.
Attach O, p 2, line
2 col 5 (Note A)
Attach O, p 2, line
14 and 23b col 5
(Note B)
(3)
(4)
Transmission
Allocator
1,171,789,360
737,577,578
O&M EXPENSE
3
Total O&M Allocated to Transmission
4
Annual Allocation Factor for O&M
Attach O, p 3, line
8 col 5
(line 3 divided by
line 1 col 3)
35,192,080
3.00%
3.00%
GENERAL AND COMMON (G&C) DEPRECIATION EXPENSE
5
Total G&C Depreciation Expense
6
Annual Allocation Factor for G&C Depreciation Expense
Attach O, p 3,
lines 10 & 11, col
5 (Note H)
(line 5 divided by
line 1 col 3)
974,916
0.08%
0.08%
TAXES OTHER THAN INCOME TAXES
7
Total Other Taxes
8
Annual Allocation Factor for Other Taxes
Attach O, p 3, line
20 col 5
(line 7 divided by
line 1 col 3)
9
Annual Allocation Factor for Expense
Sum of line 4, 6,
and 8
2,250,999
0.19%
0.19%
3.28%
INCOME TAXES
10
Total Income Taxes
11
Annual Allocation Factor for Income Taxes
Attach O, p 3, line
27 col 5
(line 10 divided by
line 2 col 3)
26,615,064
3.61%
3.61%
RETURN
12
Return on Rate Base
13
Annual Allocation Factor for Return on Rate Base
14
Annual Allocation Factor for Return
Attach O, p 3, line
28 col 5
(line 12 divided by
line 2 col 3)
Sum of line 11
and 13
58,531,643
7.94%
7.94%
11.54%
26
AIC PROJECTIONS FOR 2013
AIC Attachment GG Calculation - Page 2
(1)
Line
No.
Project Name
(2)
(3)
MTEP Project Project Gross
Number
Plant
(Note C)
1a
1b
1c
1d
Wood River-Roxford 1502 138kV line
Sidney-Paxton 138kV Reconductor 18 miles
Coffeen Plant-Coffeen, North - 2nd. Bus tie
Stallings Sub transformer/ring bus
728
870
2829
2065
$3,424,487
$5,994,479
$5,593,763
$7,298,067
(4)
Annual
Allocation
Factor for
Expense
(Page 1 line
9)
3.28%
3.28%
3.28%
3.28%
(5)
(6)
(7)
Annual
Expense
Charge
Project Net
Plant
Annual
Allocation
Factor for
Return
(Col. 3 * Col. 4)
(Note D)
$112,274.38
$196,533.50
$183,395.74
$239,272.60
$3,126,881
$5,457,597
$5,394,027
$7,229,100
(8)
Project
Annual Return Depreciation
Charge
Expense
(Page 1 line
14)
(Col. 6 * Col. 7)
11.54%
11.54%
11.54%
11.54%
(9)
$360,970.35
$630,030.56
$622,691.99
$834,534.64
(Note E)
$62,088
$121,199
$99,459
$137,933
(10)
(11)
(12)
Annual Revenue
Requirement
True-Up
Adjustment
(Sum Col. 5, 8 & 9)
(Note F)
Network
Upgrade
Charge
Sum Col. 10 &
11
(Note G)
$535,333.19
$947,763.37
$905,546.32
$1,211,740.70
$0
$0
$0
$0
535,333
947,763
905,546
1,211,741
$0
$3,600,384
2
Annual Totals
$3,600,384
3
Rev. Req. Adj For Attachment O
$3,600,384
27
AIC PROJECTIONS FOR 2013
Significant Line Expansion Projects Requiring CoCN (> $25 Million)
Project Name
LaSalle-Fox River
approval granted
Latham-Oreana
approval granted
Brokaw-S Bloomington
approval granted
Total Cost
$64 M
$26 M
$26 M
ISD
MTEP
MTEP Description
N. LaSalle-Wedron Fox River 138 kV - 24 miles new line, 2-138 kV breakers at N.
2012 MTEP05 725/726 LaSalle, 1 138 kV Breaker at Wedron Fox River. Ottawa-Wedron Fox River 138
kV - Construct 9 miles new 138 kV line, 1 new 138 kV breaker at Ottawa
2014 MTEP08
2014 MTEP08
MISO ID#
2068
Convert Oreana 345 kV Bus to 6-Position Ring Bus with 3000 A Capability;
Construct 8.5 miles of 345 kV line (2-954 kcmil ACSR conductor or equivalent
capability) from Oreana Substation to 345 kV Line 4571 tap to Latham
Substation. 3-345 kV PCB's at Oreana Substation.
2069
South Bloomington Area 345/138 kV Substation - Install 345/138 kV, 560 MVA
Transformer. Extend new 345 kV line approximately 5 miles from Brokaw
Substation to South Bloomington Substation. Install 1-138 kV PCB at South
Bloomington Substation, and 2-345 kV PCB's at Brokaw Substation
Duck Creek-Fargo
(Maple Ridge)
$78 M
2016 MTEP09
2472
Tap existing 345kV line from Duck Creek to Tazewell and create new Maple
Ridge Substation ($6.5M). Build a new supply line to the Fargo Substation by
extending 20 miles of 345kV from the new Maple Ridge Substation ($50.1M).
Create Fargo Station and install 560 MVA 345/138kV Transformer ($9.4M)
Bondville-SW Campus
approval granted
$42 M
2015 MTEP10
2992
Bondville-S.W. Campus 138 kV - Construct 8 miles of new 138 kV line. Construct
138 kV Ring Bus at Bondville (2 new PCB's) and a 138 kV Ring Bus at Champaign
S.W. Campus (4 new PCB's).
28
AIC PROJECTIONS FOR 2013
Modifications to Existing Facilities
Category
Reliability/aging infrastructure
replacement
Clearance for planned line
rating
Right of way expansion
Improved Reliability
2012-2013 CAPEX Projects
$178 million
$127 million
$22 million
$31 million
Description
196
These projects are primarily driven by the need to upgrade the transmission system based on
meeting NERC standards or Ameren Planning Criteria and Guidelines. The NERC TPL standards set
forth a set of tests that a transmission system must meet for a list of plausible scenarios, including
contingent scenarios. Ameren Planning Criteria and Guidelines (C&G) are filed each year at FERC
and constitute an additional, or complementary, set of tests that the transmission system must
meet.
54
These projects are primarily driven by the need to upgrade the transmission system to support
expected flows on the transmission circuits. Load growth, plant additions/retirements, and flow
changes due to future system expansions are primary inputs into the decision to either increase
ground clearances using existing wire or in some cases, increasing ground clearances with wire
replacement, in order to achieve higher circuit ratings.
38
These projects are driven by the need to increase the rights and rights-of-way associated with 40
transmission corridors. The primary benefit of this set of projects is increased reliability of the
system in the area of vegetation. In many cases, the existing rights-of-way are much narrower
than the widths specified in Ameren's Planning Criteria and Guidelines for reliable circuit
operation. The 2003 blackout and the recent 2011 Northeast US major outage event had
vegetation as an incipient cause. After both events, and with the adoption of the FAC-003
standard, FERC has emphasized the need for increased vegetation management efforts which
these projects support.
36
These projects are driven by the need to address reliability concerns driven by system topology,
configuration, or condition. Operating issues, including outages, usually identify these kinds of
projects. The majority of these projects involve additions of equipment in substations, e.g.
relaying and/or circuit breakers.
29
AMIL SCHEDULE 9 NITS RATE FOR 2013
AMIL Schedule 9 Rate Calculation
Page.Line
1.7
1.7
1.15
.
.
AIC Adjusted Revenue Requirement
ATXI Adjusted Revenue Requirement
Total Revenue Requirement
Ameren Illinois Divisor
Annual Cost ($/kW/Yr)
Network & P-to-P Rate ($/kW/Mo)
Jun-12
105,160,840
7,179,601
112,340,441
7,256,406
15.482
1.290
Jan-13
133,641,823
7,357,158
140,998,982
7,175,041
19.651
1.638
Change
28,480,984
177,557
28,658,540
(81,365)
4.170
0.347
Percent
27%
2%
26%
-1%
27%
27%
30
MISO WEB LINKS
• Transmission Pricing - Attachments O, GG & MM Information
• https://www.midwestiso.org/MarketsOperations/MarketInformation/Page
s/TransmissionPricing.aspx
• Ameren OASIS
• http://oasis.midwestiso.org/oasis/AMRN
• MTEP 11
• https://www.midwestiso.org/Planning/TransmissionExpansionPlanning/P
ages/MTEP11.aspx
• Schedule 26 & 26-A Indicative Charges
• https://www.midwestiso.org/Planning/TransmissionExpansionPlanning/P
ages/MTEPStudies.aspx
31
QUESTIONS?