wolverine power supply cooperative, inc.’s
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Dykema Gossett PLLCCapitol View201 Townsend Street, Suite 900Lansing, MI 48933
WWW.DYKEMA.COM
Tel: (517) 374-9100Fax: (517) 374-9191
Richard J. Aaron
Direct Dial: (517) 374-9198Direct Fax: (855) 230-2517Email: RAaron@dykema.com
Cal i forn ia | I l l ino is | Michigan | Minnesota | Texas | Washington , D.C .
4837-1831-6592.1ID\AARON, RICHARD
April 21, 2016
Mary Jo KunkleExecutive SecretaryMichigan Public Service CommissionPO Box 30221Lansing, MI 48909
Re: Case No. U-17992
Dear Ms. Kunkle:
Enclosed for electronic filing, please find Wolverine Power Supply Cooperative, Inc.’sAssessment of Ability for Meeting 2016 Through 2020 Electric Requirements of Its Members, inthe above-referenced matter.
If you have any questions, please contact me.
Sincerely,
DYKEMA GOSSETT PLLC
Richard J. Aaron
Enclosure
STATE OF MICHIGAN
BEFORE THE MICHIGAN PUBLIC SERVICE COMMISSION
* * * * *
In the matter of the investigation, on the )
Commission’s own motion, into the electric )
supply reliability plans of Michigan’s ) Case No. U-17992
electric utilities for the year 2016 through 2020 )
__________________________________________)
WOLVERINE POWER SUPPLY COOPERATIVE, INC.’S
ASSESSEMENT OF ABILITY FOR MEETING
2016 THROUGH 2020 ELECTRIC REQUIREMENTS
OF ITS MEMBERS
Wolverine Power Supply Cooperative, Inc. (Wolverine), for itself and on behalf of
its seven members1, Cherryland, Great Lakes, HomeWorks, Midwest , Presque Isle,
Wolverine Power Marketing Cooperative, Inc. (WPMC) and Spartan Renewable Energy,
Inc. (Spartan), voluntarily submits this filing, including the completed uniform template,
in response to the Michigan Public Service Commission (Commission) December 22, 2015
order (Order), in this docket.
Background
In 1998, the Commission began investigating the adequacy and reliability of the
electric generation capacity for meeting customer requirements for the Consumers Energy
Company (Consumers), DTE Electric Company (DTE Electric), and Indiana Michigan
Power Company (I&M) service territories. The Commission has since expanded the scope
of the investigations to include, among other things, the availability of transmission
capability, the effects of the companies’ retail open access programs, affiliate dealings, the
1 Five of Wolverine’s members, Cherryland Electric Cooperative (Cherryland), Great Lakes Energy
Cooperative (Great Lakes), HomeWorks Tri-County Electric Cooperative (HomeWorks), Midwest Energy
Cooperative (Midwest), and Presque Isle Electric & Gas Co-op (Presque Isle) have elected to be member-
regulated as permitted under 2008 Public Act 167.
2
Customer Choice and Electric Reliability Act, MCL 460.10, et seq., expected changes in
the wholesale market for electricity in the Midwest region, and the interconnection of
merchant generating plants. In Case No. U-14087, the Commission again expanded its
investigation to include all Michigan-regulated electric utilities, including member-
regulated cooperatives. In its December 19, 2013 order in Case No. U-17523, the
Commission conducted its investigation spanning the three-year period for 2014 through
2016 due to the expected retirement of older generating units in the state as a result of
pending new air quality requirements. In the December 4, 2014 order in Case No. U-
17751, the Commission extended the horizon to a five-year period in light of expected
capacity shortfalls in Michigan as early as 2016 and the time necessary to plan and arrange
for new capacity supplies, including new generation and demand-side options.
As in prior years, the Commission continued its investigation this year to cover the
five-year period from 2016 through 2020. Michigan electric utilities and their affiliates,
all licensed alternative energy suppliers, and Wolverine were also directed to file an
assessment of their ability to meet customers’ expected electric requirements in 2016
through 2020 by April 21, 2016. Each assessment will use the uniformly formatted table
developed in Case No. U-17751.
The Midcontinent Independent System Operator, Inc. (MISO), PJM
Interconnection, American Transmission Company, LLC, Michigan Electric Transmission
Company and the International Transmission Company are also invited to submit
comments on the issues that they believe are relevant to the Commission’s investigation.
Description of Wolverine
Wolverine is a not-for-profit generation and transmission electric cooperative
providing wholesale service to its seven members and is subject to Federal Energy
Regulatory Commission jurisdiction under the Federal Power Act. Wolverine has five
3
traditional distribution cooperative member-owners2 that purchase power from Wolverine
and resell that power at retail to approximately 268,000 member-owners located in
Michigan, Ohio and Indiana. Wolverine’s other two members, WPMC and Spartan, are
Commission-licensed alternative electric suppliers in Michigan.
Wolverine obtains capacity and energy from its own units and/or long-term power
supply contracts and balances its power supply portfolio with short-term purchases from,
and sales into, MISO. Wolverine is a MISO Transmission Owner with a transmission
system consisting of approximately 1,600 miles of 69 kV and 138 kV looped transmission
lines and associated facilities. These transmission facilities are included in the Michigan
Joint Zone under MISO’s Open Access Transmission, Energy and Operating Reserve
Markets Tariff (“MISO Tariff”), as are 69 kV radial lines and associated facilities whose
use by third parties is priced separately under Commission-approved wholesale distribution
service agreements entered into pursuant to Schedule 11 of the MISO Tariff.
Assessment of Wolverine’s 2016 through 2020 Electric Requirements and
Transmission Reliability
In response to the Commission’s Order, Wolverine staff performed an assessment
of Wolverine’s projected loads for each year within the 2016 to 2020 timeframe. This
assessment addresses what Wolverine considers to be three separate resource portfolios.
The first portfolio assessment focused on the expected needs of Wolverine’s five traditional
poles and wires distribution cooperative members: Cherryland, Great Lakes, HomeWorks,
Midwest, and Presque Isle. This assessment relied upon past usage data and any known
changes going forward, combined with historical trends for annual rates of growth. The
2 Cherryland, Great Lakes, HomeWorks, Midwest, and Presque Isle.
4
calculation was then adjusted for the known and expected effects of weather and
temperature.
The second portfolio assessment focused on Wolverine’s sixth member, WPMC.
WPMC serves industrial and commercial members under Michigan’s Customer Choice
and Electric Reliability Act as provided for under Public Act 141 of 2000, as amended by
Public Act 286 of 2008. As with the first calculation, this assessment relied upon past
usage data and any known changes going forward. No adjustments have been made for
historical rates of growth and since the loads served by WPMC are far less affected by
differences in weather, no adjustments for weather effects were made.
The final portfolio assessment focused on Wolverine’s seventh member, Spartan.
Spartan is primarily focused on the sale of renewable energy to industrial and commercial
customers under Michigan’s Customer Choice and Electric Reliability Act as provided for
under Public Act 141 of 2000, as amended by Public Act 286 of 2008. As with the previous
calculations, this assessment relied upon past usage data and any known changes going
forward. Similar to the WPMC assessment, no adjustments have been made for historical
rates of growth or weather effects.
Wolverine staff also analyzed Wolverine’s available supply portfolio for each year
during the 2016 to 2020 timeframe established by the Commission for the assessment,
including all owned generation and various capacity contracts. Additionally, as indicated
by the Commission’s Order, Wolverine compared the results of its demand forecasts with
its available supply resources. The results of the above portfolio analyses are contained in
the assessment summary in Exhibit A and the uniform template in Exhibit B.
Conclusion
Wolverine recognizes the Commission’s concern and supports its desire for
ensuring the continuing availability of adequate generation and power supply resources to
5
reliably serve the energy and capacity needs of Michigan’s industrial, commercial, and
residential customers. The Commission correctly understands that a secure power supply
as well as an adequate and reliable transmission system is necessary to maintain a reliable
level of service to all customers. In that spirit, Wolverine is pleased to submit Exhibit A
and Exhibit B containing its assessment of Wolverine’s 2016 through 2020 expected
electric requirements and available resources for serving its members.
Respectfully submitted,
WOLVERINE POWER SUPPLY
COOPERATIVE, INC.
Dated: April 21, 2016 ____________________________
By: Kimberly B. Molitor
Its: Vice President –
External Affairs
s/Kimberly B. Molitor
Exhibit A
Wolverine Power Supply Cooperative, Inc.
Assessment of Ability for Meeting Customers’ Electric Requirements
for the Period 2016 through 2020
On December 22, 2015, the Michigan Public Service Commission (Commission), in its order
in Case U-17992 (Order), directed utilities and other affected companies, including Wolverine
Power Supply Cooperative, Inc. (Wolverine), to file with the Commission “an assessment of
the ability to meet customers’ expected electric requirements for 2016 through 2020.” This
assessment is in response to the Commission’s Order.
Overview
This assessment addresses what Wolverine considers to be three separate resource portfolios:
Wolverine’s traditional poles and wires distribution cooperative member-owners (called the
“Transmission Members”)3, Wolverine Power Marketing Cooperative, Inc. (WPMC), and
Spartan Renewable Energy, Inc. (Spartan).
MISO Peak Demand Forecast for Wolverine’s Resource Portfolios
Wolverine’s coincident peak demand for its Distribution Members, WPMC, and Spartan is
inclusive of the Midcontinent Independent System Operator, Inc. (MISO) and PJM load.
Wolverine will have sufficient capacity to meet its members’ requirements during all seasons
from 2016 through 2020.
MISO and PJM Capacity Resources to Meet the Needs of its Members
1) Native Generation
Wolverine’s portfolio for its Distribution Members, WPMC, and Spartan includes
1,017 MW of summer generation capacity owned and operated by Wolverine,
including Wolverine’s new natural gas-fired generation plant in Gaylord, Michigan
that will be operational on June 1, 2016.
2) MISO Capacity Purchase
Wolverine has purchased MISO Zone 7 capacity from other entities to meet its
additional requirements for its Distribution Members, WPMC, and Spartan for 2016.
This purchased capacity has been included in the MISO Module E Capacity Tracking
(MECT) application to verify that no units were oversubscribed.
3) PJM Capacity Purchase
Wolverine has purchased capacity through an all requirements contract to serve its
obligations in PJM through 2017. After 2017, Wolverine expects to purchase its
capacity requirements from the PJM forward capacity market.
3 Cherryland Electric Cooperative, Great Lakes Energy Cooperative, Presque Isle Electric & Gas Co-
op, HomeWorks Tri-County Electric Cooperative, and Midwest Energy Cooperative.
7
4) PJM Capacity Sale Wolverine has sold its 6.65% ownership interest in two Ohio Valley Electric
Corporation (OVEC) generating facilities in the PJM forward capacity market.
Summary
Through its owned generation and additional capacity contracts, Wolverine will have sufficient
reserves in place to meet the forecasted demands during the summer peak seasons of 2016
through 2020, to meet the portfolio load requirements and reserve margins of its Distribution
Members, WPMC, and Spartan. Wolverine remains committed to delivering reliable and
competitively-priced power supply to its members.
December 22, 2015
Pursuant to the Order in Commission Case No.
U‐17992Entities are encouraged to use this form to submit a self‐assessment
of their ability to meet their customer's expected electric
requirements during the five‐year period of 2016 ‐ 2020
As directed by the Commission in the December 22, 2015 Order in Case No. U‐17992, Staff offers the attached exhibits as a tool to assist electric utilities, alternative electric suppliers, utility affiliates, and power supply cooperatives and associations in their self‐assessment submittals. As noted in the aforementioned order, companies are encouraged to submit a written narrative, which will support the data provided in these tables. Submittal of this form does not necessarily ensure complete compliance with the requirements outlined in the Order; each company should be certain that their filing meet the full extent of the Order.
Notes1. In addition to those requirements outlined by the Order, all filings should include:
a. Discussion of any observed risks associated with mid‐planning year retirement of generation assets.
b. Discussion of the plan to meet any identified capacity shortfall.c. Discussion supporting the data provided in the attached tables.
2. Definitions of key line items are included as comments on the individual cell.
3. Please report all data in the units specified by the corresponding row/column.
4. Exhibits 1, 2, and 3 provide sample calculations, including formulae, used to derive the final result.a. Any deviation from the intended formulae should be noted and justified in the narrative of the filing.
5. Each company should file either Exhibit 1 or Exhibit 2. Exhibit 1 is designed for reporting bundled service utility peak demand. Exhibit 2 is designed for alternativeenergy supplier peak demand.
Wolverine Power Supply Cooperative, Inc.
Case No:
Utility:
Date:
Exhibit 1:
Utility Bundled Service Peak Demand for the Lower Peninsula of Michigan
( a ) ( b ) ( c ) ( d ) ( e ) ( f ) ( g ) ( h ) ( i ) ( j )
Line Sample Calc. PY 2013‐14 PY 2014‐15 PY 2015‐16 PY 2016‐17 PY 2017‐18 PY 2018‐19 PY 2019‐20 PY 2020‐21
Actual Actual Actual Forecast Forecast Forecast Forecast Forecast
Peak Demand (MW)
1 Service Territory, Coincident to Bundled 0 661 549 603 628 633 638 644 650
2 Choice, Coincident to Bundled 0 0 0 0 0 0 0 0 0
3 Bundled (line 1 ‐ line 2) 0 661 549 603 628 633 638 644 650
Coincident to MISO Sys.Peak Demand (MW)
4 Service Territory 0 653 536 601 615 620 625 631 637
5 Choice 0 0 0 0 0 0 0 0 0
6 Bundled (line 4 ‐ line 5) 0 653 536 601 615 620 625 631 637
* Totals carry to Sheet 3.
* Provide actual values where available.
* Assume current proportions of Bundled service and Choice service throughout the forecast period unless there is a known change in electric service provider.
* Do not adjust for Load Modifying Resources or Demand Response Programs. Those adjustments will be accounted for in Exhibit 3.
Utility Bundled Service Peak Demand for the Upper Peninsula of Michigan
( a ) ( b ) ( c ) ( d ) ( e ) ( f ) ( g ) ( h ) ( i ) ( j )
Line Sample Calc. PY 2013‐14 PY 2014‐15 PY 2015‐16 PY 2016‐17 PY 2017‐18 PY 2018‐19 PY 2019‐20 PY 2020‐21
Actual Actual Actual Forecast Forecast Forecast Forecast Forecast
Peak Demand (MW)
7 Service Territory, Coincident to Bundled 0
8 Choice, Coincident to Bundled 0
9 Bundled (line 7 ‐ line 8) 0
Coincident to MISO Sys.Peak Demand (MW)
10 Service Territory 0
11 Choice 0
12 Bundled (line 10 ‐ line 11) 0
* Totals carry to Sheet 3.
* Provide actual values where available.
* Assume current proportions of Bundled service and Choice service throughout the forecast period unless there is a known change in electric service provider.
* Do not adjust for Load Modifying Resources or Demand Response Programs. Those adjustments will be accounted for in Exhibit 3.
Actual and Forecast including Transmission Losses (MW)
Actual and Forecast including Transmission Losses (MW)
U‐17992
_________________
_________________
Peak Demand Bundled Service
Wolverine Power Marketing Cooperative (WPMC)
Case No:
Utility:
Date:
Exhibit 2:
( a ) ( b ) ( c ) ( d ) ( e ) ( f ) ( g ) ( h ) ( i ) ( j )
Line Sample Calc. PY 2013‐14 PY 2014‐15 PY 2015‐16 PY 2016‐17 PY 2017‐18 PY 2018‐19 PY 2019‐20 PY 2020‐21
Actual Actual Actual Forecast Forecast Forecast Forecast Forecast
Peak Demand (MW)
1 LSE Peak Demand w/o Transmission Losses 0 131 127 130 180 180 180 180 180
2 Load Diversity Factor 0.98 0.98 0.98 0.98 0.98 0.98 0.98 0.98 0.98
3 Coincident Peak Demand (line 1 x line 2) 0 128 124 127 176 176 176 176 176
* Totals carry to Sheet 3.
* Provide actual values where available.
* Do not adjust for Load Modifying Resources or Demand Response Programs. Those adjustments will be accounted for in Exhibit 3.
( a ) ( b ) ( c ) ( d ) ( e ) ( f ) ( g ) ( h ) ( i ) ( j )
Line Sample Calc. PY 2013‐14 PY 2014‐15 PY 2015‐16 PY 2016‐17 PY 2017‐18 PY 2018‐19 PY 2019‐20 PY 2020‐21
Actual Actual Actual Forecast Forecast Forecast Forecast Forecast
Peak Demand (MW)
4 LSE Peak Demand w/o Transmission Losses 0 7 7 8 8 8 8 8 8
5 Load Diversity Factor 0.98 0.98 0.98 0.98 0.98 0.98 0.98 0.98 0.98
6 Coincident Peak Demand (line 4 x line 5) 0 7 7 8 8 8 8 8 8
* Totals carry to Sheet 3.
* Provide actual values where available.
* Do not adjust for Load Modifying Resources or Demand Response Programs. Those adjustments will be accounted for in Exhibit 3.
Actual and Forecast including Transmission Losses (MW)
177992___________
____
_______________
Peak Demand AES
AES Peak Demand for the Lower Peninsula of Michigan
Actual and Forecast including Transmission Losses (MW)
AES Peak Demand for the Upper Peninsula of Michigan
Spartan Renewable Energy, Inc. (Spartan)
Case No:
Utility:
Date:
Exhibit 2:
( a ) ( b ) ( c ) ( d ) ( e ) ( f ) ( g ) ( h ) ( i ) ( j )
Line Sample Calc. PY 2013‐14 PY 2014‐15 PY 2015‐16 PY 2016‐17 PY 2017‐18 PY 2018‐19 PY 2019‐20 PY 2020‐21
Actual Actual Actual Forecast Forecast Forecast Forecast Forecast
Peak Demand (MW)
1 LSE Peak Demand w/o Transmission Losses 0 10 9 9 10 10 10 10 10
2 Load Diversity Factor 0.98 0.98 0.98 0.98 0.98 0.98 0.98 0.98 0.98
3 Coincident Peak Demand (line 1 x line 2) 0 10 9 8 10 10 10 10 10
* Totals carry to Sheet 3.
* Provide actual values where available.
* Do not adjust for Load Modifying Resources or Demand Response Programs. Those adjustments will be accounted for in Exhibit 3.
U‐17992
_______________
_______________
Peak Demand AES
AES Peak Demand for the Lower Peninsula of Michigan
Actual and Forecast including Transmission Losses (MW)
Wolverine
WPMC
Spartan
Case No:
Utility:
Date:
Exhibit 3:
( a ) ( b ) ( c ) ( d ) ( e ) ( f )
Line Sample Calc. PY 2016‐2017 PY 2017‐2018 PY 2018‐2019 PY 2019‐2020 PY 2020‐2021
1 Forecasted Bundled Plus AES Non‐Coincident Peak Demand, MW (from Ex. 1, Ex. 2a and Ex. 2b) 0 826 831 836 842 848
2 Internal Demand Response Programs that are applied as an adjustment to the Peak forecast, MW 0 0 0 0 0 0
3 Adjusted Forecasted Bundled and AES Non‐Coincident Peak Demand, MW (line 1 ‐ line 2) 0 826 831 836 842 848
4 Load Diversity Factor coincident to MISO Factor, %. 98.00% 98.00% 98.00% 98.00% 98.00% 98.00%
5 Adjusted Total Peak Demand, MW (line 3 x line 4) 0 809 814 819 825 831
6 Transmission Losses, % 2.80% 2.80% 2.80% 2.80% 2.80% 2.80%
7 Adjusted Total Peak Demand, MW (line 5 ‐(line 5 x line 6)) 0 787 792 796 802 808
8 Applied Transmission Losses, MW (line 5 x line 6) 0 23 23 23 23 23
9 Adjusted Forecasted Bundled and AES Coincident Peak Demand, MW (same as line 5) 0 809 814 819 825 831
10 Planning Reserve Margin % UCAP Basis 7.10% 7.10% 7.10% 7.20% 7.10% 7.10%
11 Total Planning Reserve Margin (expected reserves), UCAP MW ((line 8 + line 9) x (1 + line 10)) 0 891 897 903 908 915
12 Company Owned, In‐State, Non‐Intermittent, MW 0 960 960 960 960 960
13 Company Owned, Out‐of‐State, Non‐Intermittent, MW 0 121 121 121 121 121
14 Company Owned, In‐State, Intermittent, MW 0 0 0 0 0 0
15 Company Owned, Out‐of‐State, Intermittent, MW 0 0 0 0 0 0
16 Total Company Owned Generation, MW (line 12 + line 13 + line 14 + line 15) 0 1,081 1,081 1,081 1,081 1,081
17 Load Modifying Resources, Treated as Capacity, MW 0 0 0 0 0 0
18 Applied Transmission Losses, MW (line 17 x line 6) 0 0 0 0 0 0
19 Total Qualified Demand Response Resources including PRMUCAP, MW ((line 17 + line 18) x (1 + line 10)) 0 0
20 PPA, In‐State Intermittent Resource, MW 0 6.0 42 42 42 42
21 PPA, Out‐of‐State Intermittent Resource, MW 0 0
22 PPA, PURPA (BTMG), MW 0
23 PPA, Intermittent (BTMG), MW 0
24 Other Forward Capacity Contract, MW ‐ In‐State 0 250 50 0 0 0
25 Other Forward Capacity Contract, MW ‐ Out‐of‐State 0 145 145 0 0 0
26 Total PPA, MW (line 20 + line 21 + line 22 + line 23 + line 24 + line 25) 0 401 237 42 42 42
27 Total Planning Resources, MW (line 16 + line 19 + line 26) 0 1,482 1,318 1,123 1,123 1,123
28 UCAP Surplus/(Shortfall), MW (line 27 ‐ line 11) 0 591 421 220 215 208
Planning Reserve Margin Requirements and Planning Resources to be Acquired (UCAP MW)
U‐17992
_______________
_______________
Planning Resources
Wolverine
Case No:
Utility:
Date:
Exhibit 4:
( a ) ( b ) ( c ) ( d ) ( e )
Demand Response Program Name Demand Response Program (MW) Credit Transmission Losses and PRM UCAP(MW) Total MW per Program Name
PY 2016‐UCAP
Total Demand Response ‐ Capacity Resources PY 2015‐2016 (MW) 0
PY 2017‐UCAP
Total Demand Response ‐ Capacity Resources PY 2016‐2017 (MW) 0
PY 2018‐UCAP
Total Demand Response ‐ Capacity Resources PY 2017‐2018 (MW) 0
PY 2019‐UCAP
Total Demand Response ‐ Capacity Resources PY 2018‐2019 (MW) 0
PY 2020‐UCAP
Total Demand Response ‐ Capacity Resources PY 2019‐2020 (MW) 0
* Expand each planning year section as necessary to accommodate all DR programs that are used as capacity resources.
U‐17992
_______________
_______________
DR Program Resources
Demand Response ‐ Capacity Resources
Wolverine
Case No:
Utility:
Date:
Exhibit 5:
( a ) ( b ) ( c ) ( d ) ( e ) ( f ) ( g ) ( h ) ( i ) ( j ) ( k ) ( l ) ( m ) ( n ) ( o ) ( p )
Fuel or Specify: Located in If outside of MI, Contracted P.A. 295
Line Electric Generation Unit Name Renewable Type LRZ 2, LRZ 7, I&M, Other Michigan (Y/N) Trans Service (Y/N) Resource (Y/N) 2016 2017 2018 2019 2020 2016 2017 2018 2019 2020
1 JUDD Unit #1 Nat Gas LRZ 7 Y N 85 85 85 85 85 79 79 79 79 79
2 JUDD Unit #2 Nat Gas LRZ 7 Y N 85 85 85 85 85 79 79 79 79 79
3 JUDD Unit #3 Nat Gas LRZ 7 Y N 85 85 85 85 85 79 79 79 79 79
4 JUDD Unit #4 Nat Gas LRZ 7 Y N 85 85 85 85 85 79 79 79 79 79
5 Gaylord Unit #1 Nat Gas LRZ 7 Y N 25 25 25 25 25 21 21 21 21 21
6 Gaylord Unit #2 Nat Gas LRZ 7 Y N 25 25 25 25 25 21 21 21 21 21
7 Gaylord Unit #3 Nat Gas LRZ 7 Y N 25 25 25 25 25 20 20 20 20 20
8 Burnips Unit #6 Nat Gas LRZ 7 Y N 23 23 23 23 23 20 20 20 20 20
9 Burnips Unit #8 Nat Gas LRZ 7 Y N 25 25 25 25 25 22 22 22 22 22
10 Hersey Unit #9 Nat Gas LRZ 7 Y N 27 27 27 27 27 22 22 22 22 22
11 Hersey Unit #10 Nat Gas LRZ 7 Y N 27 27 27 27 27 20 20 20 20 20
12 Tower Unit #4 Fuel Oil LRZ 7 Y N 22 22 22 22 22 22 22 22 22 22
13 Vestaburg Unit #8 Nat Gas LRZ 7 Y N 23 23 23 23 23 21 21 21 21 21
14 Alpine #1 Nat Gas LRZ 7 Y N 199 199 199 199 199 188 188 188 188 188
15 Alpine #2 Nat Gas LRZ 7 Y N 199 199 199 199 199 188 188 188 188 188
16 OVEC Coal Other N N 150 150 150 150 150 121 121 121 121 121
17
18
19
20
21
22
23
24
25
26
* Add rows to accommodate all generating units as necessary.
* Please use UCAP data for ICAP columns for run‐of‐river hydroelectric power, wind power and solor power resources.
UCAP (MW)
Company Owned Electric Generation Resources
U‐17992
_______________
_______________
Generation Resource List
ICAP (MW)
Wolverine
Case No:
Utility:
Date:
Exhibit 6:
( a ) ( b ) ( c ) ( d ) ( e ) ( f ) ( g ) ( h ) ( i ) ( j ) ( k ) ( l ) ( m ) ( n ) ( p ) ( q ) ( r ) ( s )
Fuel or Specify: Located in PA 295 PA 295 BTMG PURPA Other Bilateral
Line Electric Generator Name Renewable Type LRZ 2, LRZ 7, I&M, Other Michigan Y/N Y/N Y/N Y/N PPA Y/N 2016 2017 2018 2019 2020 2016 2017 2018 2019 2020
1 Campbell III Coal LRZ7 Y N N 15 15 15 15 15 15 15 15 15 15
2 Harvest Wind Farm Wind LRZ7 Y Y N 53 53 53 53 53 6 6 6 6 6
3 Deerfield Wind Farm Wind LRZ7 Y Y N 149 149 149 149 18 18 18 18
4 Michigan Wind 3 Wind LRZ7 Y Y N 153 153 153 153 18 18 18 18
5 Confidential Contract Confidential LRZ7 Y N Y 75 50 75 50
6 Confidential Contract Confidential LRZ7 Y N Y 50 50
7 Confidential Contract Confidential LRZ7 Y N Y 125 125
8
9 Wabash Valley Full Requirements Contract Mix I&M NA N Y 145 145 145 145
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
* Add rows to accommodate all generating units as necessary.
* Please use UCAP data for ICAP columns for run‐of‐river hydroelectric power, wind power and solor power resources.
ICAP MW Contracted
U‐17992
_______________
_______________
PPA Resource List
UCAP MW Contracted
Generation Resources Under PPA or Other Capacity Contract
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