exv10w92






Exhibit 10.92




			
	 	 	 
	Midwest ISO
	 	Fourth Revised Service Agreement No. 1756
	FERC Electric Tariff, Fourth Revised Volume No. 1
	 	Superseding Third Revised Service Agreement No. 1756
	 
	 	Public Version






AMENDED AND RESTATED

GENERATOR INTERCONNECTION AGREEMENT




entered into by the



Midwest Independent Transmission System Operator, Inc.



Michigan Electric Transmission Company



and Consumers Energy Company



			
	 	 	 
	Issued by: Steven G. Kozey, Issuing Officer
	 	Effective: April 22, 2010
	Issued on: April 21, 2010	 	 






 









 






Original Sheet No. 1




Amended and Restated




GENERATOR INTERCONNECTION AGREEMENT



by and among



Michigan Electric Transmission Company, LLC



and



Consumers Energy Company



and the



Midwest Independent Transmission System Operator, Inc.



 









 





Original Sheet No. 2




Amended and Restated

GENERATOR INTERCONNECTION AGREEMENT

by and among

Michigan Electric Transmission Company, LLC,

Consumers Energy Company

and the

Midwest Independent Transmission System Operator, Inc.




	 	 	 	 	 

	ARTICLE 1 - DEFINITIONS
	 	 	6	 
	 
	 	 	 	 
	ARTICLE 2 - TERM OF AGREEMENT
	 	 	10	 
	 
	 	 	 	 
	2.1 Effective Date
	 	 	10	 
	2.2 Term
	 	 	10	 
	2.3 Termination
	 	 	10	 
	2.4 Regulatory Filing
	 	 	10	 
	2.5 Survival
	 	 	10	 
	 
	 	 	 	 
	ARTICLE 3 - INTERCONNECTION SERVICE
	 	 	11	 
	 
	 	 	 	 
	3.1 Scope of Service
	 	 	11	 
	3.2 Third-Party Actions
	 	 	12	 
	 
	 	 	 	 
	ARTICLE 4 - INTERCONNECTION ASSETS
	 	 	12	 
	 
	 	 	 	 
	4.1 Reservation of Rights to Interconnection Assets
	 	 	12	 
	4.2 Modifications
	 	 	12	 
	4.3 As-Built Drawings
	 	 	12	 
	 
	 	 	 	 
	ARTICLE 5 - OPERATIONS
	 	 	13	 
	 
	 	 	 	 
	5.1 General
	 	 	13	 
	5.2 Transmission Provider and Transmission Owner Obligations
	 	 	13	 
	5.3 Consumers Obligations
	 	 	13	 
	5.4 Jointly Owned Assets
	 	 	13	 
	5.5 Access Rights
	 	 	14	 
	5.6 Switching and Tagging Rules
	 	 	14	 
	5.7 Black Start Participation
	 	 	14	 
	5.8 Reactive Power
	 	 	14	 
	5.9 System Security
	 	 	14	 
	5.10 Consumers Voltage Regulation
	 	 	15	 
	5.11 Protection and System Quality
	 	 	15	 
	5.12 Outages, Interruptions, and Disconnection
	 	 	16	 
	5.13 Operating Expenses
	 	 	18	 
	 
	 	 	 	 
	ARTICLE 6 - MAINTENANCE
	 	 	19	 
	 
	 	 	 	 
	6.1 Transmission Owner’s Obligations
	 	 	19	 
	6.2 Consumers’ Obligations
	 	 	19	 
	6.3 Jointly Owned Assets
	 	 	19	 
	6.4 Access Rights
	 	 	19	 
	6.5 Maintenance Expenses
	 	 	20	 
	6.6 Coordination
	 	 	20	 






 









 






Original Sheet No. 3




	 	 	 	 	 

	6.7 Inspections and Testing
	 	 	20	 
	6.8 Right to Observe Testing
	 	 	20	 
	6.9 Secondary Systems
	 	 	20	 
	6.10 Observation of Deficiencies
	 	 	20	 
	 
	 	 	 	 
	ARTICLE 7 - EMERGENCIES
	 	 	21	 
	 
	 	 	 	 
	7.1 Obligations
	 	 	21	 
	7.2 Notice
	 	 	21	 
	7.3 Immediate Action
	 	 	21	 
	7.4 Transmission Provider’s and Transmission Owner’s Authority
	 	 	21	 
	7.5 Consumers’ Authority
	 	 	22	 
	7.6 Audit Rights
	 	 	22	 
	 
	 	 	 	 
	ARTICLE 8 - SAFETY
	 	 	22	 
	 
	 	 	 	 
	8.1 General
	 	 	22	 
	8.2 Environmental Releases
	 	 	22	 
	 
	 	 	 	 
	ARTICLE 9 - METERING
	 	 	22	 
	 
	 	 	 	 
	9.1 General
	 	 	22	 
	9.2 Costs of Administering Metering Assets
	 	 	23	 
	9.3 Testing of Metering Assets
	 	 	23	 
	9.4 Metering Data
	 	 	23	 
	9.5 Communications
	 	 	24	 
	 
	 	 	 	 
	ARTICLE 10 - FORCE MAJEURE
	 	 	24	 
	 
	 	 	 	 
	ARTICLE 11 - INFORMATION REPORTING
	 	 	25	 
	 
	 	 	 	 
	ARTICLE 12 - PAYMENTS AND BILLING PROCEDURES
	 	 	25	 
	 
	 	 	 	 
	12.1 Invoices
	 	 	25	 
	12.2 Payments
	 	 	25	 
	12.3 Interest Charges
	 	 	26	 
	12.4 Disputes
	 	 	26	 
	 
	 	 	 	 
	ARTICLE 13 - ASSIGNMENT
	 	 	26	 
	 
	 	 	 	 
	ARTICLE 14 - INDEMNITY AND INSURANCE
	 	 	27	 
	 
	 	 	 	 
	14.1 Indemnity
	 	 	27	 
	14.2 Insurance
	 	 	27	 
	 
	 	 	 	 
	ARTICLE 15 - LIMITATION ON LIABILITY
	 	 	28	 
	 
	 	 	 	 
	ARTICLE 16 - BREACH, CURE AND DEFAULT
	 	 	28	 
	 
	 	 	 	 
	16.1 General
	 	 	28	 
	16.2 Events of Breach
	 	 	28	 
	16.3 Continued Operation
	 	 	29	 
	16.4 Cure and Default
	 	 	29	 
	16.5 Right to Compel Performance
	 	 	30	 
	 
	 	 	 	 
	ARTICLE 17 - CONFIDENTIALITY
	 	 	30	 






 









 






Original Sheet No. 4




	 	 	 	 	 

	ARTICLE 18 -AUDIT RIGHTS
	 	 	31	 
	 
	 	 	 	 
	ARTICLE 19 - DISPUTES
	 	 	31	 
	 
	 	 	 	 
	ARTICLE 20 - NOTICES
	 	 	31	 
	 
	 	 	 	 
	ARTICLE 21 - MISCELLANEOUS
	 	 	32	 
	 
	 	 	 	 
	21.1 Amendments
	 	 	32	 
	21.2 Binding Effect
	 	 	32	 
	21.3 Counterparts
	 	 	32	 
	21.4 Entire Agreement
	 	 	32	 
	21.5 Governing Law
	 	 	32	 
	21.6 Headings Not To Affect Meaning
	 	 	33	 
	21.7 Waivers
	 	 	33	 
	21.8 Termination of Predecessor Interconnection Agreement
	 	 	33	 
	 
	 	 	 	 
	EXHIBITS
	 	 	 	 
	EXHIBIT A Consumers Generation Resources
	 	 	34	 
	EXHIBIT B Interconnection Assets
	 	 	37	 
	EXHIBIT B Table 1
	 	 	38	 
	EXHIBIT C Generator Connections located in Consumers’ Distribution System
	 	 	65	 
	EXHIBIT C Consumers Energy Generator Connections Covered under Other Interconnection Agreements
	 	 	65	 






 









 






Original Sheet No. 5




Amended and Restated

GENERATOR INTERCONNECTION AGREEMENT




     THIS Amended AND RESTATED GENERATOR INTERCONNECTION AGREEMENT(the “Agreement”) is made and
entered into as of March 18th, 2010 by and among Michigan Electric Transmission Company,
LLC, a limited liability company with offices at 27175 Energy Way Novi, Michigan (herein referred
to as “METC” or “Transmission Owner”), Consumers Energy Company, a Michigan corporation with
offices at One Energy Plaza, Jackson, Michigan (herein referred to as “Consumers” or
“Interconnection Customer”), and the Midwest Independent Transmission System Operator, Inc., a
non-profit, non-stock corporation organized and existing under the laws of the State of Delaware
(herein referred to as “Midwest ISO” or “Transmission Provider”). Transmission Provider, Consumers
and Transmission Owner each may be referred to individually as a “Party,” or collectively as the
“Parties.” This Agreement amends, restates and replaces the July 24, 2008 Amendment and Restatement
of the Generator Interconnection Agreement between the Transmission Owner, Transmission Provider
and Consumers, effective on the Effective Date provided for below in Section 2.1.



WITNESSETH:




     WHEREAS, Consumers owns and operates several electric generating assets (herein referred to as
a Unit when discussing one of them, or as Generation Resources when referring to all of them) as
described in Article 1. The Unit names and generating capability ratings of the Generation
Resources are set forth in Exhibit A to this Agreement. Each Unit in the list is currently in
commercial operation; and



     WHEREAS, Transmission Provider has functional control of the operation of the Transmission
System, as defined in Article 1 of this Agreement, and is responsible for providing transmission
and interconnection service on the transmission facilities under its functional control; and



     WHEREAS, Transmission Owner owns or operates the Transmission System, whose operations are
subject to the functional control of the Transmission Provider, to which the Consumers’ Units are
interconnected, as set forth in this Agreement; and



     WHEREAS, it is necessary for Consumers’ Units to remain interconnected with the Transmission
System (as defined in Article 1), in order for said Units to continue to operate; and



     WHEREAS, the revised and restated Agreement is not intended to affect METC’s and Consumer’s
obligations to each other with regard to the following agreements:



     WHEREAS, Consumers and Transmission Owner have entered into an Operating Agreement, dated as
of April 1, 2001, as amended and restated, (herein referred to as the “Operating Agreement”) that
defines the operating responsibilities of the Transmission Owner with respect to the Transmission
System and the obligations, rights and responsibilities of Consumers to provide ancillary services
and to operate its Generation Resources in a manner



 









 





Original Sheet No. 6



that will not unduly interfere with the provision of Transmission Services by the Transmission
Owner; and




     WHEREAS, Consumers, Transmission Owner and Transmission Provider have entered into a Purchase
and Sale Agreement for Ancillary Services, dated as of April 1, 2001, as amended and restated, that
sets forth the terms and conditions under which Consumers shall use its Generation Resources to
provide ancillary services to the Transmission Owner and Transmission Provider; and



     WHEREAS, the Parties are willing to maintain the interconnection of Consumers’ Generation
Resources with the Transmission System under the terms and conditions contained herein.



     NOW, THEREFORE, in consideration of and subject to the mutual covenants contained herein, the
Parties hereto agree as follows:



ARTICLE 1

DEFINITIONS



1.1 Whenever used in this Agreement, appendices, and attachments hereto, the following terms
shall have the following meanings:




     “Black Start Capability” shall mean a generating Unit that is capable of starting
without an outside electrical supply. Said Units are specified in Exhibit A.



     “Black Start Plan” shall mean a plan utilizing Black Start Capability designed and
implemented by the Transmission Provider or Transmission Owner in conjunction with its
interconnected generation and distribution customers, Distribution System Control, other electric
systems, its Security Coordinator and ECAR, to energize portions of the Transmission System which
are de-energized as a result of a widespread system disturbance.



     “Black Start Service” shall mean the provision of service needed to energize a defined
portion of the Transmission Owner’s Transmission System, including the start up of the Generation
Resources and/or other generators, in accordance with the Transmission Provider’s or Transmission
Owner’s Black Start Plan when local power from the Transmission System is unavailable or
insufficient.



     “Commission” shall mean the Federal Energy Regulatory Commission, or any successor
agency.



     “Connection Point” shall be the point where Consumers’ Interconnection Assets connect
to Transmission Owner’s Interconnection Assets, as described in Exhibit B of this Agreement.



     “Consumers’ Incremental Cost” shall mean Consumers’ actual hourly replacement cost of
energy on Consumers’ Generation Resources, whether that energy is (a) produced by generation owned
by or under contract to Consumers or (b) purchased from a third party.



 









 





Original Sheet No. 7




     “Consumers’ Interconnection Assets” shall mean the assets identified as belonging to
Consumers in Exhibit B of this Agreement and all other assets that are necessary or desirable to
interconnect a Unit to the Transmission System reliably and safely, including all connection,
switching, transmission, distribution, safety, and communication assets, protective assets,
Telemetry and Monitoring Assets that Consumers owns or operates and maintains.



     “Consumers’ System” shall mean the assets owned, controlled and operated by Consumers
that are used to provide service to its customers.



     “ECAR” stands for the East Central Area Reliability council or a successor group.



     “Emergency” shall mean any system condition that requires automatic or immediate manual action
to prevent or limit the loss of transmission assets or generation supply that could adversely
affect the reliability of Transmission System or Consumers’ System or the systems to which either
Party is directly or indirectly connected.



     “Generation Resources” shall mean the assets used for the production of electric
energy, which are owned and operated by Consumers and directly or indirectly connected to the
Transmission System pursuant to this Agreement.



     “Good Utility Practice” shall mean any of the practices, methods and acts engaged in
or approved by a significant proportion of the electric utility industry during the relevant time
period, or any of the practices, methods and acts which, in the exercise of reasonable judgment in
light of the facts known at the time the decision was made, could have been expected to accomplish
the desired result at a reasonable cost consistent with good business practices, reliability,
safety and expedition. Good Utility Practice is not intended to be limited to the optimum practice,
method or act to the exclusion of all others, but rather to be acceptable practices, methods or
acts generally accepted in the region.



     “Governmental Authority” shall mean any federal, state, local or municipal
governmental body; any governmental, regulatory or administrative agency, commission, body or other
authority exercising or entitled to exercise any administrative, executive, judicial, legislative,
policy, regulatory or taxing authority or power; or any court or governmental tribunal.



     “Hazardous Substances” shall mean any chemicals, materials or substances defined as or
included in the definition of “hazardous substances”, “hazardous wastes”, “hazardous materials”,
“hazardous constituents”, “restricted hazardous materials”, “extremely hazardous substances”,
“toxic substances”, “contaminants”, “pollutants”, “toxic pollutants” or words of similar meaning
and regulatory effect under any applicable Environmental Law, or any other chemical, material or
substance, exposure to which is prohibited, limited or regulated by any applicable Environmental
Law. For purposes of this Agreement, the term “Environmental Law” shall mean federal, state, and
local laws, regulations, rules, ordinances, codes, decrees, judgments, directives, or judicial or
administrative orders relating to pollution or protection of the environment, natural resources or
human health and safety.



     “IEEE” is an acronym, which stands for the Institute of Electrical and Electronic
Engineers.



 









 





Original Sheet No. 8




     “Interconnection Assets” shall mean, collectively, Transmission Owner’s
Interconnection Assets and Consumers’ Interconnection Assets, or the specific Interconnection
Assets of either the Transmission Owner or Consumers, as the case may be.



     “Jointly Owned Assets” shall mean those assets in which Consumers and Transmission
Owner have undivided ownership interests. Due to the nature of substation designs, many of the
supporting substation assets (e.g., station batteries, fencing, control houses, ground grid, yard
stone, steel structures and some protective relay assets) cannot be separated by ownership and the
Parties share in the ownership of such assets. The respective ownership of such assets by
substation is shown in Exhibit B hereto.



     “Metering Assets” shall mean the assets required to provide acceptably accurate
metering of the interconnection power and energy output from the Unit and the standby power and
energy usage of the Unit. Said Metering Assets typically includes but is not limited to, metering
accuracy potential and current transformers, transducers, primary connections, secondary
connections, secondary potential and current circuits and conduit, telephone lines and access to
said Metering Assets, if necessary. The transducers used shall be capable of providing Megawatthour
and Megavarhour data.



     “Midwest ISO” shall mean the Midwest Independent Transmission System Operator, Inc.,
or its successor.



     “Midwest ISO Tariff” shall mean the Open Access Transmission, Energy and Operating
Reserve Markets Tariff on file with the Commission as it may be amended or superseded from time to
time.



     “Monitoring Assets” shall mean the assets required to determine (a) the sequence of
events for the operation of protective assets during an electrical fault, (b) the location and
characteristics of an electrical fault and (c) the quality of power provided at the Point of
Receipt.



     “NERC” is an acronym that stands for the North American Electric Reliability Council,
including any successor thereto or any regional reliability council thereof. This reliability
council oversees the development and publication of operating policies, engineering planning
principles and guides and support information to provide guidance to the regional reliability
councils and to promote electric system reliability.



     “Point of Receipt” shall be the point at which capacity and energy is provided by
Consumers, as described in Exhibit B of this Agreement.



     “Reactive Design Limitations” shall mean the reactive power capability designed into
the Unit, which were consistent with reactive power capability specifications in place when the
Unit was constructed.



     “Secondary Systems” shall mean control or power circuits that operate below 600 volts,
AC or DC, including, but not limited to, any hardware, control or protective devices, cables,
conductors, electric conduits and raceways, secondary assets panels, transducers, batteries,
chargers, and voltage and current transformers.



 









 





Original Sheet No. 9




     “Switching and Tagging Rules” shall mean the written documents describing the
switching and tagging procedures of Transmission Owner and Consumers, as they may be amended.



     “System Operator” is a generic term used to describe the individuals responsible for
the integrity or the operational control of the Transmission System and any successor thereto.



     “System Protection Assets” shall mean the assets required to protect (a) the
Transmission System, the systems of others connected to the Transmission System, and Transmission
Owner’s customers from faults occurring at the Unit, and (b) the Unit from faults occurring on the
Transmission System or on the systems of others to which the Transmission System is directly or
indirectly connected.



     “Telemetry Equipment” shall mean the assets, identified by Transmission Owner, that
are required to provide the necessary, real-time telemetry of Unit operations and status, as
required by Transmission Owner, for remote monitoring and control purposes. This typically includes
but is not limited to, remote terminal units, distributed terminal units, telemetry signal inputs,
fiber optic communication connections, transducers, pulse multipliers, isolation amplifiers, analog
inputs, digital inputs, metering pulsed accumulator inputs, power supply, dedicated telephone data
line to remote terminal units, telephone modem, telephone switching, interface terminal strips for
landing signal inputs/outputs. Telemetry Equipment may be located at Consumers’ Unit and or at
Transmission Owner’s assets.



     “Transmission Owner” shall mean Michigan Electric Transmission Company, LLC or its
successor.



     “Transmission Owner’s Interconnection Assets” shall mean the assets identified as
belonging to Transmission Owner in Exhibit B of this Agreement and all other assets that are
necessary or desirable to interconnect the Generation Resources to the Transmission System reliably
and safely, including all connection, switching, transmission, distribution, safety, and
communication assets, protective assets, Metering, Telemetry and Monitoring Assets and all
improvements, additions or extensions to the Transmission System owned or operated and maintained
by the Transmission Owner and that are attributable to or necessitated by the Generation Resources.



     “Transmission Provider” shall mean the Midwest ISO.



     “Transmission System” shall mean the facilities owned by the Transmission Owner and
controlled or operated by the Transmission Provider or Transmission Owner that are used to provide
transmission service under the Midwest ISO Tariff.



     “Transmission Service” shall include both Point-To-Point Transmission Service and
Network Integration Transmission Service provided under the Midwest ISO Tariff.



     “Unit” shall mean each of Consumers’ electric generating assets, or group of
generating assets having common Interconnection Assets, covered by this Agreement and identified
generally in the first “Whereas” clause and Exhibit A of this Agreement and more specifically
identified in the “as built” drawings provided to Transmission Owner in accordance



 









 





Original Sheet No. 10




with Section 4.3 of this Agreement, together with the other property, assets, and assets owned
and/or controlled by Consumers on the Consumers’ side of the Connection Point.



ARTICLE 2

TERM OF AGREEMENT



2.1 Effective Date




     This Agreement shall become effective on the date designated by the Commission in its order
accepting this Agreement for filing (the “Effective Date”).


2.2 Term




     This Agreement shall become effective as provided in Section 2.1 above and, unless terminated
as provided below, shall continue in full force and effect until a mutually agreed termination
date, but no later than the date on which all of the Generation Resources cease commercial
operation.


2.3 Termination




     In the event that Transmission Owner joins a Regional Transmission Organization (“RTO”) which
requires use of its own FERC-approved interconnection and operating agreement, this Agreement shall
terminate on the effective date of such new interconnection and operating agreement between
Consumers and the RTO, except to the extent necessary to resolve billing and other outstanding
matters related to service rendered under this Agreement as specified in Section 2.5.


2.4 Regulatory Filing




     Transmission Provider shall file this Agreement with the Commission as a Service Agreement
under the Midwest ISO Tariff, within the meaning of 18 C.F.R. Part 35. Consumers and Transmission
Owner agree to cooperate with Transmission Provider with respect to such filing and to provide any
information, including the rendering of testimony reasonably requested by Transmission Provider,
needed to comply with applicable regulatory requirements.


2.5 Survival




     The applicable provisions of this Agreement shall continue in effect after expiration,
cancellation, or termination hereof to the extent necessary to provide for final billings, billing
adjustments, and the determination and enforcement of liability and indemnification obligations
arising from acts or events that occurred while this Agreement was in effect.



 









 





Original Sheet No. 11




ARTICLE 3

INTERCONNECTION SERVICE



3.1 Scope of Service




     In the event future changes in either (a) design or operation of any Unit, (b) Consumers’
requirements or (c) Transmission Provider’s or Transmission Owner’s requirements resulting from the
Unit’s parallel operation with the Transmission System later necessitate additional Interconnection
Assets or modifications to the then existing Interconnection Assets herein, the Parties shall
undertake such additions and modifications as may be necessary. Before undertaking such future
additions or modifications, the Parties shall consult, develop plans and coordinate schedules of
activities, including the making of necessary amendments to this Agreement (including its
Appendices) and/or entering into new agreements, so as to insure continuous and reliable operation
of the Interconnection Assets. The cost of such additions or modifications to the Interconnection
Assets shall be borne by Consumers unless otherwise agreed upon at the time. The ownership,
operation and maintenance responsibilities for any such future additions or modifications shall be
made consistent with the responsibilities allocated in this Agreement.



     3.1.1 Except as otherwise provided under Sections 5.8 and 5.9 of this Agreement, neither
Transmission Provider nor Transmission Owner shall have an obligation under this Agreement to pay
Consumers any wheeling or other charges for electric power and/or energy transferred through
Consumers’ assets or for power or ancillary services provided by Consumers under this Agreement for
the benefit of the Transmission System.



     3.1.2 Except as otherwise provided under this Agreement, neither Transmission Provider nor
Transmission Owner shall have an obligation under this Agreement to make arrangements or pay
under applicable tariffs for transmission and ancillary services associated with the delivery of
electricity and ancillary electrical products produced by the Unit.



     3.1.3 Except as otherwise provided under this Agreement, neither Transmission Provider nor
Transmission Owner shall have an obligation under this Agreement to procure electricity and
ancillary electrical products to satisfy Consumers’ station power needs or other related
requirements.



     3.1.4 Except as otherwise provided under this Agreement, neither Transmission Provider nor
Transmission Owner shall have an obligation under this Agreement to make arrangements under
applicable tariffs for transmission, losses, and ancillary services associated with the use of
the Transmission System for the delivery of electricity and ancillary electrical products to the
Unit.



     3.1.5 Transmission Provider makes no representations to Consumers regarding the availability
of Transmission Service on the Transmission System, and Consumers agrees that the availability of
Transmission Service on the Transmission System may not be inferred or implied from Transmission
Provider’s or Transmission Owner’s execution of this Agreement. Consumers will obtain Transmission
Service on the Transmission System under a separate agreement between the Parties and in accordance
with the provisions of the Midwest ISO Tariff.



 









 





Original Sheet No. 12



3.2 Third-Party Actions




     Consumers acknowledges and agrees that, from time to time during the term of this Agreement,
other persons may develop, construct and operate, or acquire and operate generating assets in the
Transmission Provider’s service territory, and construction or acquisition and operation of any
such assets, and reservations by any such persons of Transmission Service under the Midwest ISO
Tariff may adversely affect the Unit and the availability of Transmission Service for the Unit’s
electric output. Consumers acknowledges and agrees that Transmission Provider has no obligation
under this Agreement to disclose to Consumers any information with respect to third-party
developments or circumstances, including the identity or existence of any such person or other
assets, beyond what Transmission Provider customarily provides to other similarly situated
generators, except as may be required under Article 4 of this Agreement and elsewhere in this
Agreement. Consumers and Transmission Provider make no guarantees to the other under this Agreement
with respect to Transmission Service that is available under the Midwest ISO Tariff.



ARTICLE 4

INTERCONNECTION ASSETS



4.1 Reservation of Rights to Interconnection Assets




     Except as provided in Section 5.2 hereof, each Party reserves to itself the ownership,
operation and maintenance of its Interconnection Assets and all improvements, additions or
extensions to its Interconnection Assets under this Agreement which are attributable to or
necessitated by the interconnection of the Unit.


4.2 Modifications




     Either Party may undertake modifications to its assets. In the event a Party plans to
undertake a modification that may be expected to impact the other Party’s assets, that Party shall
provide the other Party with sufficient information regarding such modification, including, without
limitation, the notice required in accordance with Article 11 of this Agreement so that the other
Party can evaluate the potential impact of such modification prior to commencement of the work. The
Party desiring to perform such work shall provide the relevant drawings, plans, and specifications
to the other Party at least ninety (90) days in advance of commencement of the work or such shorter
period upon which the Parties may agree, which agreement will not unreasonably be withheld or
delayed.


4.3 As-Built Drawings




     Upon execution of this Agreement, Consumers shall provide to Transmission Provider and
Transmission Owner current interconnection drawings and system diagrams for each of its Units,
unless the Parties agree that such drawings are not necessary. Subject to the requirements of
Article 17 of this Agreement, not later than ninety (90) days after completion of any addition to
or modification of the assets of any of said Units that may reasonably be expected to affect the
Transmission System, Consumers shall issue revised “as built” drawings to Transmission Provider and
Transmission Owner.



 









 





Original Sheet No. 13




ARTICLE 5

OPERATIONS



5.1 General




The Parties agree that they shall comply with the Operating Agreement, then-existing (or amended)
applicable manuals, standards, and guidelines of Transmission Provider, NERC, ECAR, or any
successor agency assuming or charged with similar responsibilities related to the operation and
reliability of the North American electric interconnected transmission grid. To the extent that
this Agreement does not specifically address or provide the mechanisms necessary to comply with
such Operating Agreement, Transmission Provider, NERC or ECAR manuals, standards, or guidelines,
the Parties hereby agree that each Party shall provide to the other Parties all such information as
may reasonably be required to comply with such Operating Agreement, manuals, standards, or
guidelines and shall operate, or cause to be operated, their respective assets in accordance with
such Operating Agreement, manuals, standards, or guidelines.


5.2 Transmission Provider and Transmission Owner Obligations




     Transmission Provider and Transmission Owner shall operate and control the Transmission System
and other Transmission Owner assets in a safe and reliable manner (a) in accordance with
Transmission Provider’s and Transmission Owner’s applicable operational and/or reliability
criteria, protocols, and directives (which include those of NERC and ECAR), (b) the Operating
Agreement and (c) in accordance with the provisions of this Agreement. From time to time, Consumers
will control and operate four (4) 345 kV synchronizing circuit breakers (Nos. 28H9, 28R8, 32F7 and
32H9 in the Hampton Substation) to connect or disconnect the Karn 3 or Karn 4 Units, as the case
may be, from the Transmission System. The Parties may agree from time to time that Consumers, under
the direction of the Transmission Provider or Transmission Owner, will operate certain other
Interconnection Assets of the Transmission Owner.


5.3 Consumers Obligations




     Consumers shall operate and control its Generation Resources in a safe and reliable manner in
accordance with (a) Consumers’ applicable operational and/or reliability criteria, protocols, and
directives (which shall include those of NERC and ECAR), the Operating Agreement and (c) the
provisions of this Agreement.


5.4 Jointly Owned Assets




          Operation of Jointly Owned Assets at the electric substations where Interconnection Facilities
are located will be under the direction and control of the Party with more than fifty percent (50%)
of the major equipment at each such location, unless otherwise agreed by the Parties hereto. Said
Party shall operate the Jointly Owned Assets in a manner consistent with Good Utility Practice and
the provisions of Sections 5.2 and 5.3 above, as appropriate. Each Party’s respective share of
responsibility for the costs of operation of Jointly Owned Assets shall be the same percentage as
the percentage of major equipment



 









 





Original Sheet No. 14



owned by such Party in that substation, as set forth in Exhibit B and its subsequent addendum’s.
The respective ownership of substation facilities is shown in the Wiring Diagrams for each of the
electrical substations at which Consumers’ Generation Resources are connected to the Transmission
System (see Exhibit B), reflecting ownership changes through July 24, 2008. The Wiring Diagrams
(WDs) will be updated continuously in each Party’s Drawing Management System (DMS) which is shared
between the Parties. For current ownership (reflecting ownership changes since July 24, 2008), see
the WDs in the DMS. For purposes of this Agreement, major equipment is defined as (a) main power
transformers, (b) 23 kV, 46 kV, 138 kV and 345 kV circuit breakers, (c) power system regulators and
reclosers and (d) 46 kV and 138 kV capacitor banks (any three-phase installation of such equipment
shall count as one unit of equipment). Exhibit B shall be updated with an addendum at least
annually by the Transmission Owner, and approved in writing by all Parties at least annually, to
show all changes in equipment and the effects of such changes on the determination of Jointly Owned
Asset percentages. For purposes of this Section 5.4, such submission and approval of changes shall
be in writing consistent with Section 21.1. In the case where each Party hereto owns exactly fifty
percent (50%) of the major equipment at any specific location, the Transmission Owner shall assume
the responsibility for direction and control of the operation activities as such location. In those
substations where each Party hereto owns assets, each Party shall be responsible for its
appropriate share, as set forth in Exhibit B hereto, of station power energy usage and expense.



5.5 Access Rights




     The Parties shall provide each other such access rights as may be necessary for either Party’s
performance of its respective operational obligations under this Agreement; provided that,
notwithstanding anything stated herein, a Party performing operational work within the boundaries
of the other Party’s assets must abide by the rules applicable to that site.


5.6 Switching and Tagging Rules




     The Parties shall abide by their respective Switching and Tagging Rules for obtaining
clearances for work or for switching operations on assets. The Parties will adopt mutually
agreeable Switching and Tagging Rules prior to the effective date of this Agreement.


5.7 Black Start Participation




     In accordance with Good Utility Practice, Consumers agrees to participate in Transmission
Owner’s Black Start Plan, as well as any verification testing. Nothing in this Agreement obligates
a particular Unit to provide Black Start Service.


5.8 Reactive Power




     The supply and absorption of reactive power is dealt with in the Purchase and Sale Agreement
for Ancillary Services among the Parties hereto.


5.9 System Security






 









 








Original Sheet No. 15




     During an Emergency on the Transmission System or on an adjacent transmission system, the
System Operator has the authority to direct Consumers to increase or decrease real power production
(measured in MW) and/or reactive power production (measured in MVAR), within the design and
operational limitations of any of Consumers’ Generation Resources in service at the time, in order
to maintain security on the Transmission System. In the event of such a declaration of an
Emergency, determinations: (a) that the Transmission System security is in jeopardy, and/or (b)
that there is a need to increase or decrease reactive power production, even if real power
production is adversely affected, will be made solely by the System Operator or his designated
representative. Each Unit operator will honor System Operator’s orders and directives concerning
said Unit’s real power and/or reactive power output within design and operational limitations of
the Unit’s equipment in service at the time, such that the security of the Transmission System is
maintained. Transmission Provider and Transmission Owner shall restore the Transmission System
conditions to normal to alleviate any such Emergency, in accordance with Good Utility Practice.
Consumers will be compensated by Transmission Provider or Transmission Owner for increasing or
decreasing the real power output of any of its Units as directed by the System Operator to support
the Transmission System during an Emergency by the payment of (a) Consumers’ Incremental Cost
associated with such increase or decrease in real power output or (b) at such other rate filed by a
Party and approved by the Commission including any existing tariff or rate schedule which has been
filed by the Transmission Provider, Transmission Owner or Consumers. Similarly, if the Transmission
Provider or Transmission Owner requests any of Consumers’ Units to provide or absorb reactive power
that would be outside of the Unit’s Reactive Design Limitations, requiring the Unit’s real power
output to be reduced to obtain the desired reactive power, the Transmission Provider or
Transmission Owner shall compensate Consumers at the real power rate discussed in the preceding
sentence, to the extent that the Unit had to reduce real power output to operate within its
Reactive Design Limitations, unless otherwise provided in another agreement or tariff on file with
the Commission.


5.10 Consumers Voltage Regulation




     Consumers shall have sufficient voltage regulation at each Unit to maintain an acceptable
voltage level for the equipment at the Unit during periods of time that the Unit’s generation is
off line.


5.11 Protection and System Quality




     Consumers shall, at its expense, install, maintain, and operate System Protection Assets,
including such protective and regulating devices as are identified by order, rule or regulation of
any duly constituted regulatory authority having jurisdiction, or as are otherwise necessary to
protect personnel and assets and to minimize deleterious effects to Transmission Provider’s or
Transmission Owner’s electric service operation arising from the Unit. Transmission Owner shall
install any such protective or regulating devices that may be required on Transmission Owner’s
assets in connection with the operation of the Unit at Consumers’ expense.



     5.11.1 Requirements for Protection. In compliance with applicable NERC, ECAR and Transmission
Provider’s and Transmission Owner’s requirements, Consumers shall provide, own, and maintain
relays, circuit breakers and all other devices necessary to promptly remove any fault contribution
of the Unit to any short circuit occurring on the Transmission System not



 









 





Original Sheet No. 16



otherwise isolated by Transmission Owner’s assets. Such protective assets shall include, without
limitation, a disconnecting device or switch with visible blade disconnect and load interrupting
capability to be located between the Unit and the Transmission System at an accessible, protected,
and satisfactory site selected upon mutual agreement of the Parties. The present integrated system
provides for fault clearing at the generation substations. Unit protection may not be able to
detect all short circuits, but the Parties agree that no other arrangements shall be required.
Consumers shall be responsible for protection of the Unit and Consumers’ other associated assets
from such conditions as negative sequence currents, over- or under-frequency, sudden load
rejection, over- or under-voltage, and generator loss-of-field. Consumers shall be solely
responsible for provisions to disconnect the Unit and Consumers’ other associated assets when any
of the disturbances described above occur on the Transmission System.




     5.11.2 System Power Quality. Consumers’ facilities and equipment shall not cause excessive
voltage flicker nor introduce excessive distortion to the sinusoidal voltage or current waves.
Power output from and input to the Unit shall be in accordance with the power quality standards
contained in IEEE Standards 141 — Recommended Practice for Electrical Power Distribution for
Industrial Plants (voltage flicker) and 519 — Recommended Practices and Requirements for Harmonic
Control in Electric Power Systems (harmonics). Consumers’ facilities and equipment have been
designed and constructed in accordance with then-existing standards so as not to cause excessive
voltage excursions nor cause the voltage to drop below or rise above the range maintained by
Transmission Provider or Transmission Owner in the absence of Consumers’ facilities and equipment
at the time the Unit first went into service.



     5.11.3 Inspection. Subject to the confidentiality provisions set forth in Article 17,
Transmission Provider and Transmission Owner shall have the right, but shall have no obligation or
responsibility to (a) observe Consumers’ tests and/or inspection of any of Consumers’ protective
assets directly connected to the Transmission System or interfacing with Transmission Owner’s
protective assets, (b) review the settings of any of Consumers’ protective assets; and (c) review
Consumers’ maintenance records relative to Consumers’ protective assets. Transmission Provider
and Transmission Owner may exercise the foregoing rights from time to time as deemed necessary by
Transmission Provider or Transmission Owner upon reasonable notice to Consumers. However, the
exercise or non-exercise by Transmission Provider or Transmission Owner of any of the foregoing
rights of observation, review or inspection shall be construed neither as an endorsement or
confirmation of any aspect, feature, element, or condition of the Unit or Consumers’ protective
assets or the operation thereof, nor as a warranty as to the fitness, safety, desirability, or
reliability of same.


5.12 Outages, Interruptions, and Disconnection




     5.12.1 Outage Authority and Coordination. In accordance with Good Utility Practice, each Party
may, in close cooperation with the other and upon providing notice per Section 20.2, remove from
service its assets that may impact the other Party’s assets as necessary to perform maintenance or
testing or to install or replace assets. Absent the existence or imminence of an Emergency, the
Party scheduling a removal of a facility from service will schedule such removal on a date mutually
acceptable to both Parties. Further, the Transmission Provider and Transmission Owner shall use
their best efforts to coordinate the scheduling of maintenance on Transmission Owner’s
Interconnection Assets to coincide with



 









 





Original Sheet No. 17



Consumers scheduled maintenance on its Units that may be impacted by maintenance on Transmission
Owner’s Interconnection Assets.




     5.12.2 Outage Restoration.




          5.12.2.1 Unplanned Outage. In the event of an unplanned outage of a Party’s facility
that adversely affects the other Party’s assets, the Party that owns or controls the facility
out of service will use commercially reasonable efforts to promptly restore that facility to
service.




          5.12.2.2 Planned Outage. In the event of a planned outage of a Party’s facility that
adversely affects the other Party’s assets, the Party that owns or controls the facility out
of service will use commercially reasonable efforts to promptly restore that facility to
service and in accordance with its schedule for the work that necessitated the planned
outage.



     5.12.3 Interruption. If at any time, in Transmission Provider’s or Transmission Owner’s
reasonable judgment, the continued operation of the Unit would cause an Emergency, Transmission
Provider or Transmission Owner may curtail, interrupt, or reduce energy delivered from the Unit to
the Transmission System until the condition which would cause the Emergency is corrected.
Transmission Provider or Transmission Owner shall give Consumers as much notice as is reasonably
practicable of Transmission Provider’s or Transmission Owner’s intention to curtail, interrupt, or
reduce energy delivery from the Unit in response to a condition that would cause an Emergency and,
where practicable, allow suitable time for the Parties to remove or remedy such condition before
any such curtailment, interruption, or reduction commences. In the event of any curtailment,
interruption, or reduction, Transmission Provider or Transmission Owner shall promptly
confer with Consumers regarding the conditions that gave rise to the curtailment, interruption, or
reduction, and Transmission Provider or Transmission Owner shall give Consumers
Transmission Provider’s or Transmission Owner’s recommendation, if any, concerning the timely
correction of such conditions. Transmission Provider or Transmission Owner shall promptly cease
the curtailment, interruption, or reduction of energy delivery when the condition that would cause
the Emergency ceases to exist.



     5.12.4 Disconnection.




     5.12.4.1 Disconnection after Agreement Terminates. Upon termination of the
Agreement, Transmission Provider or Transmission Owner may disconnect Consumers’ Generation
Resources from the Transmission System in accordance with a plan for disconnection upon
which the Parties agree.




     5.12.4.2 Disconnection in Event of Emergency. Subject to the provisions of Subsection
5.12.4.3 of this Agreement, Transmission Provider, Transmission Owner or Consumers shall
have the right to disconnect the Unit without notice if, in Transmission Provider’s,
Transmission Owner’s or Consumers’ sole opinion, an Emergency exists and immediate
disconnection is necessary to protect persons or property from damage or interference
caused by Consumers’ interconnection or lack of proper or properly operating protective
devices. For purposes of this Subsection 5.12.4.2, protective devices may be deemed by
Transmission Provider



 









 





Original Sheet No. 18





or Transmission Owner to be not properly operating if Transmission Provider’s or
Transmission Owner’s review under Article 6 of this Agreement has disclosed irregular or
otherwise insufficient maintenance on such devices or that maintenance records do not
exist or are otherwise insufficient to demonstrate that adequate maintenance has been and
is being performed.




     5.12.4.3 Disconnection after Under-frequency Load Shed Event. NERC Planning Criteria
require the interconnected transmission system frequency be maintained between 59.95 Hz and
60.05 Hz. In case of an under-frequency system disturbance, the Transmission System is
designed to automatically activate a five-tier load shed program. The five load sheds occur
at 59.5, 59.3, 59.1, 58.9 and 58.7 Hz, respectively. For those Units that are determined by
Transmission Provider to be large enough to impact the Transmission Provider’s system
security, each such Unit shall be capable of under-frequency operation as specified in
Appendix 1 “Isolation of Generating Units” contained in ECAR Document No. 3 -Emergency
Operations, or a higher under-frequency set point if already in place upon execution of
this Agreement. Upon notice from Consumers and if the Transmission Provider or Transmission
Owner agrees, Consumers may implement a higher under-frequency relay set point if necessary
to protect its assets for a particular Unit or Units.



     5.12.5 Continuity of Service. Notwithstanding any other provision of this Agreement,
Transmission Provider shall not be obligated to accept, and Transmission Provider may require
Consumers to curtail, interrupt or reduce deliveries of energy if such delivery of energy impairs
Transmission Provider’s or Transmission Owner’s ability to construct, install, repair, replace or
remove any of its equipment or any part to its system or if Transmission Provider or Transmission
Owner determines that curtailment, interruption or reduction is necessary because of Emergencies,
forced outages, operating conditions on its system, or any reason otherwise permitted by
applicable rules or regulations promulgated by a regulatory agency having jurisdiction over such
matters. The Parties shall coordinate, and if necessary negotiate in good faith, the timing of such
curtailments, interruptions, reductions or deliveries with respect to maintenance, investigation or
inspection of Transmission Owner’s assets or system. Consumers reserves all rights under the
Federal Power Act and applicable other federal and state laws and regulations to commence a
complaint proceeding or other action with the Commission or other Governmental Authority with
appropriate jurisdiction over the Parties to enforce the provisions of this Subsection 5.12.5.



     5.12.6 Curtailment Notice. Except in case of Emergency, in order not to interfere
unreasonably with the other Party’s operations, the curtailing, interrupting or reducing Party
shall give the other Party reasonable prior notice of any curtailment, interruption or reduction,
the reason for its occurrence, and its probable duration.


5.13 Operating Expenses




     Consumers shall reimburse Transmission Owner for all direct and indirect costs and expenses
(including but not limited to telephone circuit charges, property taxes, insurance and assets
testing) incurred by Transmission Owner in operating Transmission Owner’s Interconnection Assets,
to the extent that Transmission Owner is not otherwise recovering such costs and expenses under an
existing tariff or rate schedule which has been filed by




 











 





Original Sheet No. 19



Transmission Provider or Transmission Owner and accepted by FERC. Such costs and expenses shall be
determined by Transmission Owner in accordance with the standard practices and policies followed by
Transmission Provider or Transmission Owner for the performance of work for others in effect at the
time such operation work is performed. Payment by Consumers shall be made in accordance with the
provisions of Article 12 hereof.




ARTICLE 6

MAINTENANCE




6.1 Transmission Owner’s Obligations




     Transmission Owner shall maintain its assets, to the extent they might reasonably be expected to
have an impact on the operation of the Unit (a) in a safe and reliable manner in accordance with
applicable operational and/or reliability criteria, protocols, and directives (which include those
of NERC and ECAR), (b) in accordance with the provisions of the Operating Agreement and (c) in
accordance with the provisions of this Agreement.



6.2 Consumers’ Obligations




     Consumers shall maintain its assets, to the extent they might reasonably be expected to have an
impact on the operation of the Transmission System (a) in a safe and reliable manner in accordance
with applicable operational and/or reliability criteria, protocols, and directives (which include
those of NERC and ECAR), (b) in accordance with the provisions of the Operating Agreement and (c)
in accordance with the provisions of this Agreement.



6.3 Jointly Owned Assets




     Maintenance of Jointly Owned Assets at the electric substations where Interconnection Facilities
are located will be under the direction and control of the Party with more than fifty percent (50%)
of the major equipment at each such location, unless otherwise agreed by the Parties hereto. Said
Party shall maintain the Jointly Owned Assets in a manner consistent with Good Utility Practice and
the provisions of Sections 6.1 and 6.2 above, as appropriate. Each Party’s respective share of
responsibility for the costs of maintenance of Jointly Owned Assets shall be the same percentage as
the percentage of major equipment owned by such Party in that substation, as set forth in Exhibit B
and its subsequent addendum. For purposes of this Agreement, major equipment is defined as set
forth in Section 5.4 hereto. Exhibit B shall be updated with an addendum at least annually by the
Transmission Owner, and approved in writing by Consumers, to show all changes in equipment and the
effects of such changes on the determination of Jointly Owned Asset percentages. In the case where
each Party hereto owns exactly fifty percent (50%) of the major equipment at any specific location,
the Transmission Owner shall assume the responsibility for direction and control of the maintenance
activities at such location.



6.4 Access Rights




     The Parties shall provide each other such access rights as may be necessary for either Party’s
performance of their respective maintenance and/or construction obligations under this Agreement;
provided that, notwithstanding anything stated herein, a Party performing



 









 





Original Sheet No. 20



maintenance and/or construction work within the boundaries of the other Party’s assets must abide
by the rules applicable to that site.




6.5 Maintenance Expenses




     Consumers shall reimburse Transmission Owner for all direct and indirect costs and expenses
(including but not limited to inspection, repair and replacement) incurred by Transmission Owner in
maintaining Transmission Owner’s Interconnection Assets, to the extent that Transmission Owner is
not otherwise recovering such costs and expenses under an existing tariff or rate schedule which
has been filed by Transmission Provider or Transmission Owner and accepted by FERC. Such costs and
expenses shall be determined by Transmission Owner in accordance with the standard practices and
policies followed by Transmission Provider or Transmission Owner for the performance of work for
others in effect at the time such operation work is performed. Payment by Consumers shall be made
in accordance with the provisions of Article 12 of this Agreement.



6.6 Coordination




     The Parties agree to confer regularly to coordinate the planning and scheduling of preventative and
corrective maintenance. Each Party shall conduct preventive and corrective maintenance activities
as planned and scheduled in accordance with this Section 6.5 and the Operating Agreement.



6.7 Inspections and Testing




     Each Party shall perform routine inspection and testing of its assets in accordance with Good
Utility Practice as may be necessary to ensure the continued interconnection of each Unit with the
Transmission System in a safe and reliable manner.



6.8 Right to Observe Testing




     Each Party shall, at its own expense, have the right to observe the testing of any of the other
Party’s assets whose performance may reasonably be expected to affect the reliability of the
observing Party’s assets. Each Party shall notify the other Party in advance of its performance of
tests of its assets, and the other Party may have a representative attend and be present during
such testing.



6.9 Secondary Systems




     Each Party agrees to cooperate with the other in the inspection, maintenance, and testing of those
Secondary Systems directly affecting the operation of a Party’s assets which may reasonably be
expected to impact the other Party. Each Party will provide advance notice to the other Party
before undertaking any work in these areas, especially in electrical circuits involving circuit
breaker trip and close contacts, current transformers, or potential transformers.



6.10 Observation of Deficiencies




 









 








Original Sheet No. 21




     If a Party observes any deficiencies or defects on, or becomes aware of a lack of scheduled
maintenance and testing with respect to, the other Party’s assets that might reasonably be expected
to adversely affect the observing Party’s assets, the observing Party shall either (a) provide
notice to the other Party that is prompt under the circumstance or (b) deem such observation an
Emergency to life or property and immediately disconnect the Unit pursuant to Subsection
5.12.4.2 of this Agreement, and the other Party shall make any corrections required in accordance
with Good Utility Practice.



ARTICLE 7

EMERGENCIES




7.1 Obligations




     Each Party agrees to comply with NERC and ECAR Emergency procedures and Transmission Provider,
Transmission Owner and Consumers Emergency procedures, as applicable, with respect to Emergencies.



7.2 Notice




     Transmission Provider or Transmission Owner shall provide Consumers with oral notification
that is prompt under the circumstances of an Emergency that may reasonably be expected to affect
Consumers’ operation of any or all of its Generation Resources, to the extent Transmission Provider
or Transmission Owner is aware of the Emergency. Consumers shall provide Transmission Provider and
Transmission Owner with oral notification that is prompt under the circumstances of an Emergency
that may reasonably be expected to affect the Transmission System, to the extent Consumers is aware
of the Emergency. In lieu of oral notification described in the preceding two sentences, the
Parties may agree in advance to use other electronic notification means. To the extent the Party
becoming aware of an Emergency is aware of the facts of the Emergency, such notification shall
describe the Emergency, the extent of the damage or deficiency, its anticipated duration, and the
corrective action taken and/or to be taken. Any such notification given pursuant to this Section
7.2 shall be followed as soon as practicable with written notice.



7.3 Immediate Action




     In case of an Emergency, the Party becoming aware of the Emergency may, in accordance with Good
Utility Practice, take such action as is reasonable and necessary to prevent, avoid, or mitigate
injury, danger, and loss, including disconnection pursuant to Subsection 5.12.4.2 of this
Agreement.



7.4 Transmission Provider’s and Transmission Owner’s Authority




     Transmission Provider or Transmission Owner may, consistent with Good Utility Practice, take
whatever actions with regard to the Transmission System as it may deem necessary during an
Emergency in order to (a) preserve public health and safety, (b) preserve the reliability of the
Transmission System, (c) limit or prevent damage and (d) expedite



 









 





Original Sheet No. 22



restoration of service. Transmission Provider or Transmission Owner shall use reasonable efforts
to minimize the effect of such actions on the Unit.




7.5 Consumers’ Authority




     Consumers may, consistent with Good Utility Practice, take whatever actions with regard to the Unit
as it may deem necessary during an Emergency in order to (a) preserve public health and safety, (b)
preserve the reliability of the Unit, (c) limit or prevent damage and (d) expedite restoration of
service. Consumers shall use reasonable efforts to minimize the effect of such actions on the
Transmission System.



7.6 Audit Rights




     Each Party shall keep and maintain records of actions taken during an
Emergency that may reasonably be expected to impact the other Party’s assets and make such records
available for third-party independent audit upon the request and expense of the party affected by
such action. Any such request for an audit will be no later than twelve (12) months following the
action taken.



ARTICLE 8

SAFETY




8.1 General




     The Parties agree that all work performed by a Party that may reasonably be expected to affect
another Party shall be performed in accordance with Good Utility Practice and all applicable laws,
regulations, and other requirements pertaining to the safety of persons or property. A Party
performing work within the boundaries of another Party’s assets must abide by the safety rules
applicable to the site.



8.2 Environmental Releases




     Each Party shall notify the other Parties, first orally and then in writing, of the release of any
Hazardous Substances or any type of remedial activities, such as asbestos or lead abatement, which
may reasonably be expected to affect another Party, as soon as possible but not later than
twenty-four (24) hours after the Party becomes aware of the occurrence, and shall promptly furnish
to the other Parties copies of any reports filed with any governmental agencies addressing such
events.



ARTICLE 9

METERING




9.1 General




     Transmission Owner shall provide, install, own and maintain Metering Assets necessary to meet its
obligations under this Agreement. Notwithstanding the foregoing sentence, Consumers, if mutually
agreed by the Parties, may provide and install some, or all,



 









 





Original Sheet No. 23



of said Metering Assets, as per Transmission Owner’s specifications. The Parties agree that, as to
all Connection Points in existence as of the effective date of this Agreement, no new Metering
Assets or arrangements shall be required. If necessary, Metering Assets shall be either located or
adjusted, at Transmission Provider’s or Transmission Owner’s option, in such manner to account for
(a) any transformation or interconnection losses between the location of the meter and the Point of
Receipt and (b) any station auxiliary power load of the generating unit. Metering quantities, in
analog and/or digital form, shall be provided to Consumers upon request. The Parties also agree
that Consumers shall continue to maintain records of the Megawatthour and Megavarhour values
collected from existing meters on the generating units and provide the information recorded to
Transmission Provider or Transmission Owner upon request.




9.2 Costs of Administering Metering Assets




     All costs associated with the administration of Metering Assets and the provision of metering data
to Consumers shall be born by Consumers. The costs of administration and of providing metering data
shall be separately itemized on Transmission Owner’s invoices to Consumers pursuant to Article 12
of this Agreement. All costs associated with changes to Metering Assets requested by Consumers,
shall be borne by Consumers and shall be invoiced pursuant to
Article 12 of this Agreement.



9.3 Testing of Metering Assets




     Transmission Owner shall, at Consumers’ expense, inspect and test all Metering Assets not less than
once every year, unless an extension of the testing cycle is agreed upon by the Parties. If
requested to do so by Consumers and at Consumers’ expense, Transmission Owner shall inspect or test
Metering Assets more frequently. Transmission Owner shall give reasonable notice of the time when
any inspection or test shall take place and Consumers may have representatives present at the test
or inspection. If Metering Assets is found to be inaccurate or defective, it shall be adjusted,
repaired or replaced at Consumers’ expense, in order to provide accurate metering. If Metering
Assets fails to register, or if the measurement made by Metering Assets during a test varies by
more than two percent (2%) from the measurement made by the standard Metering Assets used in the
test, adjustment shall be made correcting all measurements made by the inaccurate Metering Assets
for (a) the actual period during which inaccurate measurements were made, if the period can be
determined, or (b) a period equal to one-half of the elapsed time since the last test of the
Metering Assets.



9.4 Metering Data




     9.4.1 When the Metering Assets location is not at the Point of Receipt, Metering Assets
readings shall be adjusted to account for appropriate transformer and line losses, and when
applicable, the station auxiliary power load of the Unit.



     9.4.2 At Consumers’ expense, all metered data shall be telemetered to one or more locations
designated by Transmission Provider and one or more locations designated by Consumers.



 









 





Original Sheet No. 24




9.5 Communications




     9.5.1 At Consumers’ expense, Consumers shall maintain satisfactory operating communications
with System Operator or representative, as designated by Transmission Provider or Transmission
Owner. Consumers has provided standard voice and facsimile communications in the control room of
each of its Units through use of the public telephone system. Consumers has also provided a 4-wire,
full duplex data circuit (or circuits) operating at a minimum of 9600 baud, or at other baud rates
as reasonably specified by Transmission Provider or Transmission Owner. The data circuit(s) extend
from each Consumers’ Unit to a location, or locations, specified by Transmission Provider or
Transmission Owner. Any required maintenance of such communications assets shall be performed at
Consumers’ expense, and may be performed by Consumers or by Transmission Owner. Operational
communications shall be activated and maintained under, but not be limited to, the following
events: system paralleling or separation, scheduled and unscheduled shutdowns, equipment
clearances, and hourly and daily load data exchanges. To the extent required by applicable rules
and regulations, Consumers shall (a) request permission from the System Operator prior to opening
or closing circuit breakers that affect the Transmission System, (b) carry out switching orders
from the
System Operator in a timely manner and (c) keep the System Operator advised of the Unit’s
operational capabilities as required for reliable operation of the Transmission System.



     9.5.2 For all Units 1 MW or larger, a Remote Terminal Unit (“RTU”), or equivalent data
collection and transfer equipment acceptable to Consumers and Transmission Owner, has been
installed to gather accumulated and instantaneous data to be telemetered to a location, or
locations, designated by Transmission Owner through use of dedicated point-to-point data circuits
as indicated in Subsection 9.5.1 of this Agreement. Instantaneous bidirectional analog real power
and reactive power flow information, circuit breaker status information, instantaneous analog
voltage information, metering information, and disturbance monitoring information, as determined by
Transmission Provider or Transmission Owner, must be telemetered directly to the location, or
locations, specified by Transmission Provider or Transmission Owner.



ARTICLE 10

FORCE MAJEURE




     10.1 An event of Force Majeure means any act of God, labor disturbance, act of the public
enemy, war, insurrection, riot, fire, storm or flood, explosion, breakage or accident to machinery
or assets, any curtailment, order, regulation or restriction imposed by governmental military or
lawfully established civilian authorities, or any other cause beyond a Party’s reasonable control.
A Force Majeure event does not include an act of negligence or intentional wrongdoing.



     10.2 If either Party is rendered unable, wholly or in part, by Force Majeure, to carry out its
obligations under this Agreement, then, during the continuance of such inability, the obligation of
such Party shall be suspended except that Consumers’ obligation under Section 5.11 of this
Agreement to provide protection while operating in parallel with the Transmission



 









 





Original Sheet No. 25



System shall not be suspended. The Party relying on Force Majeure shall give written notice of
Force Majeure to the other Party as soon as practicable after such event occurs. Upon the
conclusion of Force Majeure, the Party heretofore relying on Force Majeure shall, with all
reasonable dispatch, take all necessary steps to resume the obligation previously suspended.




     10.3 Any Party’s obligation to make payments already owing shall not be suspended by Force Majeure.



ARTICLE 11

INFORMATION REPORTING




     Each Party shall, in accordance with Good Utility Practice, promptly provide to the other Parties
all relevant information, documents, or data regarding the Party’s assets which may reasonably be
expected to pertain to the reliability of the other Parties’ assets and/or which has been
reasonably requested by the other Parties.



ARTICLE 12

PAYMENTS AND BILLING PROCEDURES




12.1 Invoices




     Any invoices for reimbursable services provided to another Party under this Agreement during the
preceding month shall be prepared within a reasonable time after the first day of each month. Each
invoice shall delineate the month in which services were provided, shall fully describe the
services rendered and shall
be itemized to reflect the services performed or provided. The invoice shall be paid so that the
other Party will receive the funds by the 20th day following the date of such invoice,
or the first business day thereafter if the payment date falls on other than a business day. All
payments shall be made in immediately available funds payable to another Party, or by wire transfer
to a bank named by the Party being paid, provided that payments expressly required by this
Agreement to be mailed shall be mailed in accordance with Section 12.2.



12.2 Payments




     Any payments to be made by Consumers under this Agreement shall be made to Transmission Owner at
the following address:


Michigan Electric Transmission Company, LLC

P.O. Box 673971

Detroit, Ml 48267-3971

Attn: Accounting Department



If paying by wire transfer, please see the wiring instructions on the invoice.




     Any payments to be made by Transmission Owner under this Agreement shall be made to Consumers at
the following address:



 









 





Original Sheet No. 26



Consumers Energy Company

One Energy Plaza

Jackson, Michigan 49201

Attn: Treasurer




     The Parties shall provide the names of appropriate contact personnel, as are set forth in this
Agreement or otherwise, to each other after this Agreement is executed and shall keep said listing
of names and addresses up to date.



12.3 Interest Charges




     Interest on any unpaid amounts shall be calculated in accordance with the methodology specified for
interest on refunds in the Commission’s regulations at 18 CFR. §35.19 (a)(2)(iii). Interest on
delinquent amounts shall be calculated from the due date of the invoice to the date of payment.
When payments are made by mail, invoices shall be considered as having been paid on the date of
receipt by Transmission Owner or Consumers, as the case may be.



12.4 Disputes




     In the event of a billing dispute between Transmission Owner and Consumers, the Parties shall
continue to provide services and pay all invoiced amounts not in dispute. While the dispute is
being resolved, the Parties shall continue to provide services and pay all invoiced amounts not in
dispute. Following resolution of the dispute, the prevailing Party shall be entitled to receive the
disputed amount, as finally determined to be payable, along with interest accrued through the date
on which payment is made at the interest rate pursuant to Section 13.3. Payment shall be due within
ten (10) days of resolution.



ARTICLE 13

ASSIGNMENT



13.1 This Agreement shall inure to the benefit of and be binding upon the successors and
assigns of the respective parties hereto. This Agreement shall not be transferred or otherwise
alienated by any Party without the other Parties’ prior written consent, which consent shall not be
unreasonably withheld, provided that any assignee shall expressly assume assignor’s obligations
hereunder and, unless expressly agreed to by the other Parties, no assignment shall relieve the
assignor of its obligations hereunder in the event its assignee fails to perform. Any attempted
assignment, transfer or other alienation without such consent
shall be void and not merely voidable.



13.2 Notwithstanding the above, the Transmission Provider or Transmission Owner shall be
permitted to assign or otherwise transfer this Agreement, or its rights, duties and obligations
hereunder, in whole or in part, by operation of law or otherwise, without the prior written consent
of Consumers, to any successor to or transferee of the direct or indirect ownership or operation of
all or part of the transmission system to which the Generation Resources are connected. Upon the
assumption by any such permitted assignee of the assigning Transmission Provider’s or Transmission
Owner’s rights, duties and obligations hereunder, the





 









 








Original Sheet No. 27



assigning Transmission Provider or Transmission Owner shall be released and discharged therefrom to
the extent provided in the assignment agreement.



13.3 Notwithstanding the above, Consumers may assign this Agreement to a bank pursuant to the terms
of an Assignment and Security Agreement without the prior written consent of Transmission Provider
or Transmission Owner provided that such assignment shall not be effective as to Transmission
Provider or Transmission Owner until it receives a fully executed copy thereof.




ARTICLE 14

INDEMNITY AND INSURANCE




14.1 Indemnity




     The Parties shall at all times assume all liability for, and shall indemnify and save the other
Parties harmless from any and all damages, losses, claims, demands, suits, recoveries, costs, legal
fees, expenses for injury to or death of any person or persons whomsoever, or for any loss,
destruction of or damage to any property of third persons, firms, corporations or other entities
that occurs on its own system and that arises out of or results from, either directly or
indirectly, its own assets or assets controlled by it, unless caused by the sole negligence, or
intentional wrongdoing, of another Party.



14.2 Insurance




     14.2.1 The Parties agree to maintain, at their own cost and expense, the following insurance
coverages for the life of this Agreement in the manner and amounts, at a minimum, as set forth
below:




	 	(a)	 	Workers’ Compensation Insurance in accordance with all applicable State, Federal, and
Maritime Law.
	 
	 	(b)	 	Employer’s Liability insurance in the amount of $1,000,000 per accident.
	 
	 	(c)	 	Commercial General Liability or Excess Liability Insurance in the amount of $25,000,000
per occurrence.
	 
	 	(d)	 	Automobile Liability Insurance for all owned, non-owned, and hired vehicles in the amount
of $5,000,000 each accident.





     14.2.2 A Party may, at its option, [A] be an approved self-insurer for the insurances required in
1.(a) and (d); and [B] maintain such deductibles and/or retentions under the insurance required in
1.(b) and (c) as is maintained by other similarly situated companies engaged in a similar business.
The Parties agree that all amounts of self-insurance, retentions and/or deductibles are the
responsibility of, and shall be borne by, the Party whom makes such an election.



     14.2.3 Within fifteen (15) days of the Effective Date and thereafter when requested, in writing,
but not more than once every 12 months, during the term of this Agreement (including



 









 





Original Sheet No. 28



any extensions) each Party shall provide to the other Parties properly executed and current
certificates of insurance or evidence of approved self-insurance status with respect to all
insurance required to be maintained by such Party under this Agreement. Certificates of insurance
shall provide the following information:





	 	(a)	 	Name of insurance company, policy number and expiration date.
	 
	 	(b)	 	The coverage maintained and the limits on each, including the amount of deductibles or
retentions, which shall be for the account of the Party maintaining such policy.
	 
	 	(c)	 	The insurance company shall endeavor to provide thirty (30) days prior written notice of
cancellation to the certificate holder.





ARTICLE 15

LIMITATION ON LIABILITY




     NO PARTY SHALL IN ANY EVENT BE LIABLE TO THE OTHER PARTIES FOR ANY SPECIAL, INCIDENTAL, EXEMPLARY,
PUNITIVE OR CONSEQUENTIAL DAMAGES SUCH AS, BUT NOT LIMITED TO, LOST PROFITS, REVENUE OR GOOD WILL,
INTEREST, LOSS BY REASON OF SHUTDOWN OR NON-OPERATION OF EQUIPMENT OR MACHINERY, INCREASED EXPENSE
OF OPERATION OF EQUIPMENT OR MACHINERY, COST OF PURCHASED OR REPLACEMENT POWER OR SERVICES OR
CLAIMS BY CUSTOMERS, WHETHER SUCH LOSS IS BASED ON CONTRACT, WARRANTY, NEGLIGENCE, STRICT LIABILITY
OR OTHERWISE.



ARTICLE 16

BREACH, CURE AND DEFAULT




16.1 General




     A breach of this Agreement (“Breach”) shall occur upon the failure by a Party to perform or observe
any material term or condition of this Agreement. Default of this Agreement (“Default”) shall occur
upon the failure of a Party in Breach of this Agreement to cure such Breach in accordance with the
provisions of Section 16.4 of this Agreement.



16.2 Events of Breach




     A Breach of this Agreement shall include:



     16.2.1 The failure to pay any amount when due;



     16.2.2 The failure to comply with any material term or condition of this Agreement, including but
not limited to any material Breach of a representation, warranty or covenant made in this
Agreement;



 









 





Original Sheet No. 29




     16.2.3 If a Party: (a) becomes insolvent; (b) files a voluntary petition in bankruptcy under any
provision of any federal or state bankruptcy law or shall consent to the filing of any bankruptcy
or reorganization petition against it under any similar law; (c) makes a general assignment for the
benefit of its creditors or (d) consents to the appointment of a receiver, trustee or liquidator;



     16.2.4 Assignment of this Agreement in a manner inconsistent with the terms of this Agreement;



     16.2.5 Failure of a Party to provide such access rights, or a Party’s attempt to revoke or
terminate such access rights, as provided under this Agreement; or



     16.2.6 Failure of a Party to provide information or data to the other Parties as required under
this Agreement, provided the Party entitled to the information or data under this Agreement
requires such information or data to satisfy its obligations under this Agreement.



16.3 Continued Operation




     In the event of a Breach or Default by a Party, the Parties shall continue to operate and maintain,
as applicable, such DC power systems, protection and Metering Assets, Telemetering Assets, SCADA
equipment, transformers, Secondary Systems, communications assets, building assets, software,
documentation, structural components, and other assets and appurtenances that are reasonably
necessary for Transmission Provider or Transmission Owner to operate and maintain the Transmission
System and for Consumers to operate and maintain the Unit, in a safe and reliable manner.



16.4 Cure and Default




     Upon the occurrence of an event of Breach, the Party or Parties not in Breach (hereinafter the
“Non-Breaching Party”), when it becomes aware of the Breach, shall give written notice of the
Breach to the Breaching Party and to any other person the Parties to this Agreement identify in
writing to the other Parties in advance. Such notice shall set forth, in reasonable detail, the
nature of the Breach, and where known and applicable, the steps necessary to cure such Breach. Upon
receiving written notice of the Breach hereunder, the Breaching Party shall have thirty (30) days
to cure such Breach. If the Breach is such that it cannot be cured within thirty (30) days, the
Breaching Party will commence in good faith all steps as are reasonable and appropriate to cure the
Breach within such thirty (30) day time period and thereafter diligently pursue such action to
completion. In the event the Breaching Party fails to cure the Breach, or to commence reasonable
and appropriate steps to cure the Breach, within thirty (30) days of becoming aware of the Breach;
the Breaching Party will be in Default of the Agreement.



 









 





Original Sheet No. 30




16.5 Right to Compel Performance




     Notwithstanding the foregoing, upon the occurrence of an event of Default, the non-Defaulting Party
or Parties shall be entitled to: (a) commence an action to require the Defaulting Party to remedy
such Default and specifically perform its duties and obligations hereunder in accordance with the
terms and conditions hereof and (b) exercise such other rights and remedies as it may have in
equity or at law.



ARTICLE 17

CONFIDENTIALITY



17.1 All information regarding a Party (the “Disclosing Party”) that is furnished directly or
indirectly to the another Party (the “Recipient”) pursuant to this Agreement and marked
“Confidential” shall be deemed “Confidential Information”. Notwithstanding the foregoing,
Confidential Information does not include information that (i) is rightfully received by Recipient
from a third party having an obligation of confidence to the Disclosing Party, (ii) is or becomes
in the public domain through no action on Recipient’s part in violation of this Agreement, (iii) is
already known by Recipient as of the date hereof, or (iv) is
developed by Recipient independent of any Confidential Information of the Disclosing Party.
Information that is specific as to certain data shall not be deemed to be in the public domain
merely because such information is embraced by more general disclosure in the public domain.




     17.1.1 Recipient shall keep all Confidential Information strictly confidential and not disclose
any Confidential Information to any third party for a period of two (2) years from the date the
Confidential Information was received by Recipient, except as otherwise provided herein.



     17.1.2 Recipient may disclose the Confidential Information to its affiliates and its affiliates’
respective directors, officers, employees, consultants, advisors, and agents who need to know the
Confidential Information for the purpose of assisting Recipient with respect to its obligations
under this Agreement. Recipient shall inform all such parties, in advance, of the confidential
nature of the Confidential Information. Recipient shall cause such parties to comply with the
requirements of this Agreement and shall be responsible for the actions, uses, and disclosures of
all such parties.



     17.1.3 If Recipient becomes legally compelled or required to disclose any of the Confidential
Information (including, without limitation, pursuant to the policies, methods, and procedures of
the FERC, including the OASIS Standards of Conduct, or other Regulatory Authority), Recipient will
provide the Disclosing Party with prompt written notice thereof so that the Disclosing Party may
seek a protective order or other appropriate remedy. Recipient will furnish only that portion of
the Confidential Information which its counsel considers legally required, and Recipient will
cooperate, at the Disclosing Party’s expense, with the Disclosing Party’s counsel to enable the
Disclosing Party to obtain a protective order or other reliable assurance that confidential
treatment will be accorded the Confidential Information. It is further agreed that, if, in the
absence of a protective order, Recipient is nonetheless required to disclose any Confidential
Information, Recipient will furnish only that portion of the Confidential Information which its
counsel considers legally required.




 











 





Original Sheet No. 31




ARTICLE 18

AUDIT RIGHTS




     Subject to the requirements of confidentiality under Article 17 of this Agreement, each Party
shall have the right, during normal business hours, and upon prior reasonable notice to another
Party, to audit one another’s accounts and records pertaining to the Party’s performance and/or
satisfaction of obligations arising under this Agreement. Said audit shall be performed at the
offices where such accounts and records are maintained and shall be limited to those portions of
such accounts and records that relate to obligations under this Agreement.



ARTICLE 19

DISPUTES




     The Dispute Resolution Procedures set forth in the Midwest ISO Tariff shall apply to all
disputes arising under this Agreement.



ARTICLE 20

NOTICES



20.1 Any notice, demand or request required or permitted to be given by a Party to another and any
instrument required or permitted to be tendered or delivered by a Party to another may be so given,
tendered or delivered, as the case may be, by depositing the same in any United States Post Office
with postage prepaid, for transmission by certified or registered mail, addressed to the Party, or
personally delivered to the Party, at the address set out below:



To Transmission Owner:



Michigan Electric Transmission Company, LLC

27175 Energy Way

Novi, Ml 48377

Attn: Legal Department — Contracts



To Consumers:



Consumers Energy Company

1945 W. Parnall Road

Jackson, Michigan 49201

Attn: Director of Staff — Generation



To Transmission Provider:



Midwest Independent Transmission System Operator, Inc.

Attn: Manager, Interconnection Planning

701 City Center Drive

Carmel, IN 46032









 









 











Original Sheet No. 32



20.2 The Parties shall use standard telephone circuits as the primary communication link for
generation dispatch communications, including with respect to dispatching energy in the event of an
Emergency and declaring unit capability. The Parties shall provide the names and telephone numbers
of appropriate contact personnel, as are set forth in this Agreement or otherwise, to each other
after this Agreement is executed and shall keep said listing of names and telephone numbers up to
date.




ARTICLE 21

MISCELLANEOUS




21.1 Amendments




     This Agreement may be amended by and only by a written instrument duly executed by the Parties
hereto. No change or modification as to any of the provisions hereof shall be binding on any Party
unless approved in writing and approved by the duly authorized officers of the Parties.
Notwithstanding the foregoing, nothing contained herein shall be construed as affecting in any way
the right of Transmission Provider, Transmission Owner or Consumers to unilaterally make
application to the Commission for a change in rates, terms or conditions of service under Sections
205 and 206 of the Federal Power Act and pursuant to the Commission’s Rules and Regulations
promulgated thereunder. Transmission Provider reserves the right to file rate schedules with the
Commission concerning any services Transmission Provider deems necessary for reliable and orderly
bulk power system management, including but not limited to any standby or related services that may
arise from a failure by Consumers to meet its schedule of deliveries across the assets covered by
this Agreement.



21.2 Binding Effect




     This Agreement and the rights and obligations hereof, shall be binding upon and shall inure
to the benefit of the successors and assigns of the Parties hereto.



21.3 Counterparts




     This Agreement may be executed in any number of counterparts, and each executed counterpart
shall have the same force and effect as an original instrument.



21.4 Entire Agreement




     This Agreement constitutes the entire agreement among the Parties hereto with reference to
the subject matter hereof and its execution superseded all previous agreements, discussions,
communications and correspondence with respect to said subject matter. The terms and conditions of
this Agreement and every Exhibit referred to herein shall be amended, as mutually agreed to by the
Parties, to comply with changes or alterations made necessary by a valid applicable order of any
governmental regulatory authority, or any court, having jurisdiction hereof.



21.5 Governing Law





 









 








Original Sheet No. 33




     The validity, interpretation and performance of this Agreement and each of its provisions
shall be governed by the applicable laws of the State of Michigan, exclusive of its conflict of
laws principles.



21.6 Headings Not To Affect Meaning




     The descriptive headings of the various Articles and Sections of this Agreement have been
inserted for convenience of reference only and shall in no way modify or restrict any of the terms
and provisions hereof.



21.7 Waivers




     Any waiver at any time by a Party of its rights with respect to a default under this
Agreement, or with respect to any other matters arising in connection with this Agreement, shall
not be deemed a waiver or continuing waiver with respect to any subsequent default or other
matter.



21.8 Termination of Predecessor Interconnection Agreement




     On the Effective Date, the July 24, 2008 Amendment and Restatement of the Generator
Interconnection Agreement between Transmission Provider, Transmission Owner and Consumers shall
terminate and be replaced by this Agreement with regard to the Units covered by this Agreement,
except insofar as necessary to resolve billing and related matters arising from service rendered
and other events occurring before the Effective Date.



     IN WITNESS WHEREOF, the Parties hereto have caused this Agreement to be duly executed by
their duly authorized officers.



	 	 	 	 	 

	MICHIGAN ELECTRIC TRANSMISSION COMPANY, LLC	 	 
	 
	 	 	 	 
	By

	 	/s/ Daniel J. Oginsky
	 	 
	 

	 	 	 	 
	 

	 	Daniel J. Oginsky	 	 
	Title

	 	Sr. V.P. & General Counsel	 	 
	 
	CONSUMERS ENERGY COMPANY	 	 
	 
	 	 	 	 
	By

	 	/s/ James R. Coddington
	 	1-20-2010
	 

	 	 	 	 
	 

	 	James R. Coddington	 	 
	Title

	 	V.P. Generation Ops.	 	APVD AS TO FORM
	 
	 	 	 	 
	MIDWEST INDEPENDENT TRANSMISSION SYSTEM OPERATOR, INC.	 	 
	 
	 	 	 	 
	By

	 	/s/ WILLIAM C. PHILLIPS	 	9-18-10
	 

	 	 	 	 
	 

	 	WILLIAM C. PHILLIPS	 	 
	Title

	 	Vice President	 	 
	 

	 	Standards Compliance & Strategy	 	 
	 
	 	 	 	 





 









 





     



					
	 
	 	EXHIBIT A — CONSUMERS GENERATION RESOURCES
	 	Original Sheet No. 34






	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 
	 	 	 	 	 	 	Summer	 	Winter	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 
	 	 	Nameplate	 	Net	 	Net	 	 	 	 	 	 	 	 	 	 	 	 	 	AGC	 	Black	 	 	 	 
	 	 	Rated	 	Demonstrated	 	Demonstrated	 	 	 	 	 	 	 	 	 	 	 	AGC	 	Ramp	 	Start	 	Synch	 	 
	Generating Unit	 	MVA (1)	 	MW Capability	 	MW Capability	 	Kilovolts	 	RPM	 	Cooling	 	Capable	 	MW/Min	 	Capable	 	Breaker(s)	 	Comments
	Campbell 1
	 	 	312.0	 	 	 	260.0	 	 	 	260.0	 	 	 	16.0	 	 	 	3,600	 	 	Hydrogen	 	Yes	 	 	1	 	 	No	 	 	199	 	 	 
	Campbell 2
	 	 	492.0	 	 	 	355.0	 	 	 	360.0	 	 	 	20.0	 	 	 	3,600	 	 	Water/Hydrogen	 	Yes	 	 	1	 	 	No	 	 	299	 	 	 
	Campbell A
	 	 	21.9	 	 	 	13.0	 	 	 	17.0	 	 	 	13.8	 	 	 	3,600	 	 	Air	 	No	 	 	0	 	 	Yes	 	 	C16	 	 	 
	Cobb 1
	 	 	81.2	 	 	 	61.0	 	 	 	61.0	 	 	 	14.4	 	 	 	3,600	 	 	Hydrogen	 	No	 	 	0	 	 	No	 	 	199	 	 	Cobb 1-3 are capable of 68 MW each except that with 3 units running the combined output is boiler limited to 183 MW.
	Cobb 2
	 	 	81.2	 	 	 	61.0	 	 	 	61.0	 	 	 	14.4	 	 	 	3,600	 	 	Hydrogen	 	No	 	 	0	 	 	No	 	 	299	 	 	Cobb 1-3 are capable of 68 MW each except that with 3 units running the combined output is boiler limited to 183 MW.
	Cobb 3
	 	 	81.2	 	 	 	61.0	 	 	 	61.0	 	 	 	14.4	 	 	 	3,600	 	 	Hydrogen	 	No	 	 	0	 	 	No	 	 	399	 	 	Cobb 1-3 are capable of 68 MW each except that with 3 units running the combined output is boiler limited to 183 MW.
	Cobb 4
	 	 	184.0	 	 	 	158.0	 	 	 	160.0	 	 	 	18.0	 	 	 	3,600	 	 	Hydrogen	 	Yes	 	 	1	 	 	No	 	 	499	 	 	 
	Cobb 5
	 	 	184.0	 	 	 	158.0	 	 	 	160.0	 	 	 	18.0	 	 	 	3,600	 	 	Hydrogen	 	Yes	 	 	1	 	 	No	 	 	599	 	 	 
	Gaylord 1
	 	 	18.8	 	 	 	14.0	 	 	 	17.0	 	 	 	13.8	 	 	 	3,600	 	 	Air	 	No	 	 	0	 	 	Yes	 	 	116	 	 	 
	Gaylord 2
	 	 	18.8	 	 	 	14.0	 	 	 	17.0	 	 	 	13.8	 	 	 	3,600	 	 	Air	 	No	 	 	0	 	 	Yes	 	 	216	 	 	 
	Gaylord 3
	 	 	18.8	 	 	 	14.0	 	 	 	17.0	 	 	 	13.8	 	 	 	3,600	 	 	Air	 	No	 	 	0	 	 	Yes	 	 	316	 	 	 
	Gaylord 4
	 	 	18.8	 	 	 	14.0	 	 	 	17.0	 	 	 	13.8	 	 	 	3,600	 	 	Air	 	No	 	 	0	 	 	Yes	 	 	416	 	 	 
	Gaylord 5
	 	 	21.9	 	 	 	14.0	 	 	 	17.0	 	 	 	13.8	 	 	 	3,600	 	 	Air	 	No	 	 	0	 	 	No	 	 	516	 	 	 
	Karn 1
	 	 	336.0	 	 	 	255.0	 	 	 	255.0	 	 	 	16.0	 	 	 	3,600	 	 	Hydrogen	 	No	 	 	0	 	 	No	 	 	199	 	 	 
	Karn 2
	 	 	320.0	 	 	 	260.0	 	 	 	260.0	 	 	 	16.0	 	 	 	3,600	 	 	Hydrogen	 	No	 	 	0	 	 	No	 	 	299	 	 	 
	Karn 3
	 	 	814.7	 	 	 	638.0	 	 	 	638.0	 	 	 	26.0	 	 	 	3,600	 	 	Water/Hydrogen	 	Yes	 	 	6	 	 	No	 	 	28R8/28H9	 	 	 
	Karn 4
	 	 	835.0	 	 	 	638.0	 	 	 	638.0	 	 	 	26.0	 	 	 	3,600	 	 	Water/Hydrogen	 	Yes	 	 	6	 	 	No	 	 	32F7/32H9	 	 	 
	Ludington 1 (gen)
	 	 	388.0	 	 	 	312.0	 	 	 	312.0	 	 	 	20.0	 	 	 	112.5	 	 	Air	 	Yes	 	 	9	 	 	No (2)	 	 	116	 	 	NDC is 312 MW but can operate at 340 MWg (338 MW net) at full pond.
	Ludington 2 (gen)
	 	 	388.0	 	 	 	312.0	 	 	 	312.0	 	 	 	20.0	 	 	 	112.5	 	 	Air	 	Yes	 	 	9	 	 	Yes	 	 	216	 	 	NDC is 312 MW but can operate at 340 MWg (338 MW net) at full pond.
	Ludington 3 (gen)
	 	 	388.0	 	 	 	312.0	 	 	 	312.0	 	 	 	20.0	 	 	 	112.5	 	 	Air	 	Yes	 	 	9	 	 	Yes	 	 	316	 	 	NDC is 312 MW but can operate at 340 MWg (338 MW net) at full pond.






 









 






     



					
	 
	 	EXHIBIT A — CONSUMERS GENERATION RESOURCES
	 	Original Sheet No. 35






	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 
	 	 	 	 	 	 	Summer	 	Winter	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 
	 	 	Nameplate	 	Net	 	Net	 	 	 	 	 	 	 	 	 	 	 	 	 	AGC	 	Black	 	 	 	 
	 	 	Rated	 	Demonstrated	 	Demonstrated	 	 	 	 	 	 	 	 	 	 	 	AGC	 	Ramp	 	Start	 	Synch	 	 
	Generating Unit	 	MVA(1)	 	MW Capability	 	MW Capability	 	Kilovolts	 	RPM	 	Cooling	 	Capable	 	MW/Min	 	Capable	 	Breaker(s)	 	Comments
	Ludington 4 (gen)
	 	 	388.0	 	 	 	312.0	 	 	 	312.0	 	 	 	20.0	 	 	 	112.5	 	 	Air	 	Yes	 	 	9	 	 	No (2)	 	 	416	 	 	NDC is 312 MW but can operate at
340
 MWg (338 MW net) at full pond.
	Ludington 5 (gen)
	 	 	388.0	 	 	 	312.0	 	 	 	312.0	 	 	 	20.0	 	 	 	112.5	 	 	Air	 	Yes	 	 	9	 	 	Yes	 	 	516	 	 	NDC is 312 MW but can operate at
340
 MWg (338 MW  net) at full pond. 
	Ludington 6 (gen)
	 	 	388.0	 	 	 	312.0	 	 	 	312.0	 	 	 	20.0	 	 	 	112.5	 	 	Air	 	Yes	 	 	9	 	 	No (2)	 	 	616	 	 	NDC is 312 MW but can  operate at
340
 MWg (338 MW net) at full pond.
	Morrow A
	 	 	20.7	 	 	 	14.0	 	 	 	17.0	 	 	 	13.8	 	 	 	3,600	 	 	Air	 	No	 	 	0	 	 	Yes	 	 	A16	 	 	 
	Morrow B
	 	 	20.7	 	 	 	14.0	 	 	 	17.0	 	 	 	13.8	 	 	 	3,600	 	 	Air	 	No	 	 	0	 	 	Yes	 	 	B16	 	 	 
	Straits 1
	 	 	25.0	 	 	 	16.0	 	 	 	21.0	 	 	 	13.8	 	 	 	3,600	 	 	Air	 	No	 	 	0	 	 	Yes	 	 	S16	 	 	 
	Thetford 1
	 	 	39.5	 	 	 	30.0	 	 	 	37.0	 	 	 	13.8	 	 	 	3,600	 	 	Air	 	No	 	 	0	 	 	Yes	 	 	116	 	 	 
	Thetford 2
	 	 	39.5	 	 	 	29.0	 	 	 	37.0	 	 	 	13.8	 	 	 	3,600	 	 	Air	 	No	 	 	0	 	 	Yes	 	 	216	 	 	 
	Thetford 3
	 	 	39.5	 	 	 	30.0	 	 	 	37.0	 	 	 	13.8	 	 	 	3,600	 	 	Air	 	No	 	 	0	 	 	Yes	 	 	316	 	 	 
	Thetford 4
	 	 	39.5	 	 	 	30.0	 	 	 	37.0	 	 	 	13.8	 	 	 	3,600	 	 	Air	 	No	 	 	0	 	 	Yes	 	 	416	 	 	 
	Thetford 5
	 	 	20.7	 	 	 	15.0	 	 	 	17.0	 	 	 	13.8	 	 	 	3,600	 	 	Air	 	No	 	 	0	 	 	Yes	 	 	516	 	 	 
	Thetford 6
	 	 	20.7	 	 	 	15.0	 	 	 	17.0	 	 	 	13.8	 	 	 	3,600	 	 	Air	 	No	 	 	0	 	 	Yes	 	 	616	 	 	 
	Thetford 7
	 	 	20.7	 	 	 	14.0	 	 	 	17.0	 	 	 	13.8	 	 	 	3,600	 	 	Air	 	No	 	 	0	 	 	Yes	 	 	716	 	 	 
	Thetford 8
	 	 	20.7	 	 	 	15.0	 	 	 	18.0	 	 	 	13.8	 	 	 	3,600	 	 	Air	 	No	 	 	0	 	 	Yes	 	 	816	 	 	 
	Thetford 9
	 	 	20.7	 	 	 	14.0	 	 	 	17.0	 	 	 	13.8	 	 	 	3,600	 	 	Air	 	No	 	 	0	 	 	Yes	 	 	916	 	 	 
	Weadock 7
	 	 	202.0	 	 	 	155.0	 	 	 	155.0	 	 	 	18.0	 	 	 	3,600	 	 	Hydrogen	 	Yes	 	 	1	 	 	No	 	 	799	 	 	 
	Weadock 8
	 	 	184.0	 	 	 	155.0	 	 	 	155.0	 	 	 	18.0	 	 	 	3,600	 	 	Hydrogen	 	Yes	 	 	1	 	 	No	 	 	899	 	 	 
	Weadock A
	 	 	21.9	 	 	 	13.0	 	 	 	17.0	 	 	 	13.8	 	 	 	3,600	 	 	Air	 	No	 	 	0	 	 	Yes	 	 	A16	 	 	 
	Whiting 1
	 	 	125.0	 	 	 	102.0	 	 	 	102.0	 	 	 	14.4	 	 	 	3,600	 	 	Hydrogen	 	Yes	 	 	1	 	 	No	 	 	199	 	 	 
	Whiting 2
	 	 	125.0	 	 	 	102.0	 	 	 	102.0	 	 	 	14.4	 	 	 	3,600	 	 	Hydrogen	 	Yes	 	 	1	 	 	No	 	 	299	 	 	 
	Whiting 3
	 	 	156.3	 	 	 	122.0	 	 	 	124.0	 	 	 	15.5	 	 	 	3,600	 	 	Hydrogen	 	Yes	 	 	1	 	 	No	 	 	399	 	 	 
	Whiting A
	 	 	21.9	 	 	 	13.0	 	 	 	17.0	 	 	 	13.8	 	 	 	3,600	 	 	Air	 	No	 	 	0	 	 	Yes	 	 	46A	 	 	 
	Alcona Hydro 1
	 	 	4.4	 	 	 	4.0	 	 	 	4.0	 	 	 	5.0	 	 	 	90	 	 	Air	 	NA	 	NA	 	Yes	 	 	116/166	 	 	 
	Alcona Hydro 2
	 	 	4.4	 	 	 	4.0	 	 	 	4.0	 	 	 	5.0	 	 	 	90	 	 	Air	 	NA	 	NA	 	Yes	 	 	216/166	 	 	 
	Calkins Bridge Hydro 1
	 	 	0.6	 	 	 	0.4	 	 	 	0.4	 	 	 	4.8	 	 	 	180	 	 	Air	 	NA	 	NA	 	Yes	 	 	116/166	 	 	Also known as Allegan Hydro 
	Calkins Bridge Hydro 2
	 	 	1.1	 	 	 	0.9	 	 	 	0.9	 	 	 	4.8	 	 	 	120	 	 	Air	 	NA	 	NA	 	Yes	 	 	216/166	 	 	Also known as Allegan Hydro
	Calkins Bridge Hydro 3
	 	 	1.5	 	 	 	1.2	 	 	 	1.2	 	 	 	4.8	 	 	 	113	 	 	Air	 	NA	 	NA	 	No	 	 	316/166	 	 	Also known as Allegan Hydro
	Cooke Hydro 1
	 	 	3.3	 	 	 	1.5	 	 	 	1.5	 	 	 	2.5	 	 	 	180	 	 	Air	 	NA	 	NA	 	Yes	 	 	116/166	 	 	 
	Cooke Hydro 2
	 	 	3.3	 	 	 	3.0	 	 	 	3.0	 	 	 	2.5	 	 	 	180	 	 	Air	 	NA	 	NA	 	Yes	 	 	216/166	 	 	 
	Cooke Hydro 3
	 	 	3.3	 	 	 	3.0	 	 	 	3.0	 	 	 	2.5	 	 	 	180	 	 	Air	 	NA	 	NA	 	Yes	 	 	316/166	 	 	 






 









 






     



					
	 
	 	EXHIBIT A — CONSUMERS GENERATION RESOURCES
	 	Original Sheet No. 36






	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 
	 	 	 	 	 	 	Summer	 	Winter	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 
	 	 	Nameplate	 	Net	 	Net	 	 	 	 	 	 	 	 	 	 	 	 	 	AGC	 	Black	 	 	 	 
	 	 	Rated	 	Demonstrated	 	Demonstrated	 	 	 	 	 	 	 	 	 	 	 	AGC	 	 Ramp	 	 Start	 	Synch	 	 
	Generating Unit	 	MVA (1)	 	MW Capability	 	MW Capability	 	Kilovolts	 	RPM	 	Cooling	 	 Capable	 	MW/Min	 	Capable	 	Breaker(s)	 	Comments
	Croton Hydro 1
	 	 	3.8	 	 	 	2.9	 	 	 	2.9	 	 	 	7.2	 	 	 	225	 	 	Air	 	NA	 	NA	 	Yes	 	 	116/246	 	 	 
	Croton Hydro 2
	 	 	3.8	 	 	 	2.9	 	 	 	2.9	 	 	 	7.2	 	 	 	225	 	 	Air	 	NA	 	NA	 	Yes	 	 	216/246	 	 	 
	Croton Hydro 3
	 	 	1.4	 	 	 	1.3	 	 	 	1.3	 	 	 	7.2	 	 	 	150	 	 	Air	 	NA	 	NA	 	Yes	 	 	316/246	 	 	 
	Croton Hydro 4
	 	 	1.6	 	 	 	1.3	 	 	 	1.3	 	 	 	7.2	 	 	 	150	 	 	Air	 	NA	 	NA	 	Yes	 	 	416/246	 	 	 
	Five Channels 1
	 	 	3.3	 	 	 	3.2	 	 	 	3.2	 	 	 	2.5	 	 	 	150	 	 	Air	 	NA	 	NA	 	Yes	 	 	116/166	 	 	 
	Five Channels 2
	 	 	3.3	 	 	 	3.2	 	 	 	3.2	 	 	 	2.5	 	 	 	150	 	 	Air	 	NA	 	NA	 	Yes	 	 	216/166	 	 	 
	Foote Hydro 1
	 	 	3.3	 	 	 	3.3	 	 	 	3.3	 	 	 	5.0	 	 	 	90	 	 	Air	 	NA	 	NA	 	Yes	 	 	116/366	 	 	 
	Foote Hydro 2
	 	 	3.3	 	 	 	3.3	 	 	 	3.3	 	 	 	5.0	 	 	 	90	 	 	Air	 	NA	 	NA	 	Yes	 	 	216/366	 	 	 
	Foote Hydro 3
	 	 	3.3	 	 	 	3.3	 	 	 	3.3	 	 	 	5.0	 	 	 	90	 	 	Air	 	NA	 	NA	 	Yes	 	 	316/366	 	 	 
	Hodenpyl Hydro 1
	 	 	8.9	 	 	 	9.2	 	 	 	9.2	 	 	 	7.5	 	 	 	120	 	 	Air	 	NA	 	NA	 	Yes	 	 	116/266	 	 	 
	Hodenpyl Hydro 2
	 	 	8.9	 	 	 	9.2	 	 	 	9.2	 	 	 	7.5	 	 	 	120	 	 	Air	 	NA	 	NA	 	Yes	 	 	216/266	 	 	 
	Loud Hydro 1
	 	 	2.2	 	 	 	2.2	 	 	 	2.2	 	 	 	2.5	 	 	 	120	 	 	Air	 	NA	 	NA	 	Yes	 	 	116/266	 	 	 
	Loud Hydro 2
	 	 	2.2	 	 	 	2.2	 	 	 	2.2	 	 	 	2.5	 	 	 	120	 	 	Air	 	NA	 	NA	 	Yes	 	 	216/266	 	 	 
	Mio Hydro 1
	 	 	2.7	 	 	 	2.2	 	 	 	2.2	 	 	 	2.5	 	 	 	80	 	 	Air	 	NA	 	NA	 	Yes	 	 	116/166	 	 	 
	Mio Hydro 2
	 	 	2.7	 	 	 	2.2	 	 	 	2.2	 	 	 	2.5	 	 	 	80	 	 	Air	 	NA	 	NA	 	Yes	 	 	216/166	 	 	 
	Rogers Hydro 1
	 	 	1.9	 	 	 	1.5	 	 	 	1.5	 	 	 	7.5	 	 	 	150	 	 	Air	 	NA	 	NA	 	Yes	 	 	116/166	 	 	 
	Rogers Hydro 2
	 	 	1.9	 	 	 	1.5	 	 	 	1.5	 	 	 	7.5	 	 	 	150	 	 	Air	 	NA	 	NA	 	Yes	 	 	216/166	 	 	 
	Rogers Hydro 3
	 	 	1.9	 	 	 	1.5	 	 	 	1.5	 	 	 	7.5	 	 	 	150	 	 	Air	 	NA	 	NA	 	Yes	 	 	316/166	 	 	 
	Rogers Hydro 4
	 	 	1.9	 	 	 	1.5	 	 	 	1.5	 	 	 	7.5	 	 	 	150	 	 	Air	 	NA	 	NA	 	Yes	 	 	416/166	 	 	 
	Tippy Hydro 1
	 	 	7.1	 	 	 	7.0	 	 	 	7.0	 	 	 	7.5	 	 	 	109	 	 	Air	 	NA	 	NA	 	Yes	 	 	116/266/126	 	 	 
	Tippy Hydro 2
	 	 	7.1	 	 	 	7.0	 	 	 	7.0	 	 	 	7.5	 	 	 	109	 	 	Air	 	NA	 	NA	 	Yes	 	 	216/266/126	 	 	 
	Tippy Hydro 3
	 	 	7.1	 	 	 	7.0	 	 	 	7.0	 	 	 	7.5	 	 	 	109	 	 	Air	 	NA	 	NA	 	Yes	 	 	316/266/126	 	 	 
	Webber Hydro 1
	 	 	3.3	 	 	 	2.3	 	 	 	2.3	 	 	 	7.2	 	 	 	164	 	 	Air	 	NA	 	NA	 	Yes	 	 	116/166	 	 	 
	Webber Hydro 2
	 	 	1.3	 	 	 	1.0	 	 	 	1.0	 	 	 	2.5	 	 	 	200	 	 	Air	 	NA	 	NA	 	Yes	 	 	216	 	 	 








 




			
	Notes:
	 
	(1)	 	Rated MVA represents generator machine capability limits. Turbine or main transformer limits
may be more restrictive.
	 
	(2)	 	Ludington units 1,4 and 6 need to have one of the other units on line before they can be
started.






 











 





Original Sheet No. 37




EXHIBIT B — INTERCONNECTION ASSETS



General



The Parties agree that certain assets located at each of the electrical Substations at which
Consumers’ Generation Resources are connected to the Transmission System are an integral part of
the assets required by the Parties to provide services under their respective charters and that the
physical partition would be impossible, impractical and wholly inconsistent with the purposes for
which this Agreement is made. Said assets are deemed to be Jointly Owned Assets. In general, said
assets include, but in some of the electrical Substations shall not be limited to, the following:




	 	 	 

	Foundations

	 	All foundations not identified as belonging to a specific piece of assets in the
Plant Accounting Records.
	 
	Structures

	 	All steel support structures.
	 
	Station wiring

	 	All buswork, control cables, batteries, battery chargers and ground grids.
	 
	Fencing

	 	All chain-link fencing surrounding or used within the specific electrical Substation.
	 
	Control house

	 	Any building located within the Substation used to house relaying, controls or
telemetry equipment beneficial to and used by both Parties.
	 
	Stone

	 	All stone used in the Substation yards, driveways and drains.





At each of the substations listed in this Exhibit B, an allocated percentage of the Jointly Owned
Assets is determined for each Party hereto, in accordance with the provisions of this Agreement



For each of the electrical Substations at which Consumers’ Generation Resources are connected to
the Transmission System, the specific assets allocated to and owned by Consumers are identified
below as Consumers’ Interconnection Assets. In certain 345 kV Substations, specific breakers and
associated assets that have been designated for operation by Consumers are also specifically
identified as Transmission Owner’s Interconnection Assets.



Some of the electrical Substations containing Interconnection Assets also contain Distribution
System assets owned by Consumers. Unless said Distribution System assets are directly involved in
the connection of Consumers’ Generation Resources to the Transmission System, they are not
described in the description of assets that follow.



The balance of the assets in each electrical Substation are allocated to and owned by the
Transmission Owner and considered a part of the Transmission System.



Wiring Diagrams (WDs) will be updated continuously in each Party’s Drawing Management System (DMS)
which is shared between the Parties and approved in writing by the Local Distribution Company to
show changes in ownership. For current ownership (reflecting ownership changes since July 24,
2008), see the WDs in the DMS.





 









 








Original Sheet No. 38




Exhibit B-Table 1




Jointly Owned Asset Ownership by Percent of Major Equipment

Addendum 1 — Final 01-01-10




Substations

Jointly Owned Assets

Percentage Split by Major Equipment Count

(Substations with 100% Ownership by Major Equipment Count Not Included)




	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 
	 	 	 	 	 	 	 	 	 	 	Generation	 	 	 	 	 	 
	 	 	 	 	 	 	 	 	 	 	Owned by	 	 	 	 	 	 
	 	 	 	 	 	 	 	 	 	 	Local	 	 	 	 	 	Last
	 	 	 	 	 	 	 	 	 	 	Distribution	 	Third-Party	 	Revision
	Substation Name	 	Distribution	 	Transmission	 	Company	 	Assets	 	Date
	Campbell 138 kV
	 	 	0.00	 	 	 	69.23	 	 	 	30.25	 	 	 	0.51	 	 	 	01/01/10	 
	Cobb Plant
	 	 	47.22	 	 	 	25.00	 	 	 	27.78	 	 	 	 	 	 	 	04/29/02	 
	Gaylord
	 	 	44.44	 	 	 	44.44	 	 	 	11.12	 	 	 	 	 	 	 	01/01/10	 
	Karn Plant
	 	 	0.00	 	 	 	63.64	 	 	 	36.36	 	 	 	 	 	 	 	01/01/10	 
	Morrow 1
	 	 	66.67	 	 	 	23.33	 	 	 	6.67	 	 	 	3.33	 	 	 	01/01/10	 
	Thetford
	 	 	0.00	 	 	 	92.00	 	 	 	8.00	 	 	 	 	 	 	 	04/29/02	 
	Weadock
	 	 	35.14	 	 	 	24.32	 	 	 	40.54	 	 	 	 	 	 	 	01/01/10	 
	Whiting
	 	 	31.58	 	 	 	31.58	 	 	 	36.84	 	 	 	 	 	 	 	01/01/10	 








 




			
	1	 	 At 120kV and above, third-party related assets will be included as part of the Transmission
assets for purposes of making this calculation. Also, the third-party may share in the financial
responsibility associated with O&M activities.




Changes, relative to previous revisions (addendums), are shown in bold type. Major equipment is
defined in Section 5.4 of the GIA.





 









 









Original Sheet No. 39




Generator Connections located at Substations in the Transmission System 




Campbell 1&2 Plant



The Campbell 1&2 Plant consists of three generating Units, known as Unit 1 (consisting of
generators 1A and 1B), Unit 2 and Unit A. (The Campbell 3 Plant is located at the same site, but
has separate interconnection facilities and is covered by a separate generator interconnection
agreement.)



The Connection Point for Units 1,2 and A are in the Campbell 138 kV Substation (see Wiring Diagram
#93, Sheet 31 attached).



The Points of Receipt for all the Units in the Campbell 1&2 Plant are deemed to be the respective
Connection Points.



Consumers’ Interconnection Assets



Consumers owns the following assets at the Campbell 138 kV Substation (Wiring Diagram #93, Sheet
31):




	 	 	 

	Transformer Bank

	 	No. A (located outside of substation; not included in JOA calc)
	 
	Circuit Breakers

	 	Nos. 199, 299, 799, 899* and 16A (16A is rated < 23kV and not considered major
equipment per GIA definition).
	 
	Switches

	 	Nos. 99A, 195,196, 295, 296, 709, 793, 795, 796, 809*, 893*, 895* and 896*
	 
	 	 
	Circuit Connections

	 	All wire, cable or buswork electrically connecting the switches identified
above to the Circuit Breakers identified above and to the main or transfer buswork
	 
	 	 
	Relay & Controls

	 	All relays and controls associated with the Circuit Breakers identified above
	 
	Foundations

	 	All foundations supporting the Circuit Breakers identified above








 




			
	*	 	Jointly Owned asset with Michigan Public Power Agency (4.8%) and Wolverine Power Supply
Cooperative (1.8%)





Transmission Owner Interconnection Assets



Transmission Owner owns the following assets at the Campbell 138 kV Substation (Wiring Diagram #93,
Sheet 31):




	 	 	 

	Transformer Bank

	 	No. 5
	 
	Circuit Breakers

	 	Nos. 148, 188, 288, 388, 488, 500, 566 and 588
	 
	Switches

	 	Nos. 108, 144,145, 146, 184, 185, 186, 208, 284, 285, 286, 308, 384,
385, 386, 408,484,485,486, 505, 506, 508, 509, 545, 546, 584, 585,
586,594, 1020 and 1121






 









 






Original Sheet No. 40




	 	 	 

	Circuit Connections

	 	All wire, cable or bus work electrically connecting the switches identified
above to the Circuit Breakers identified above and to the main or transfer
bus work
	 
	Relay and Controls

	 	All relays and controls associated with the Circuit Breakers identified above
	 
	Foundations

	 	All foundations supporting the Circuit Breakers identified above





Jointly Owned Assets — Percentage Split by Major Equipment Count




Campbell 138 kV Substation — See Exhibit B — Table 1




 









 








Original Sheet No. 41




CEII MATERIAL






 









 








Original Sheet No. 42




Cobb Generating Plant Complex



The Cobb Generating Plant Complex consists of five generating Units, known as Units 1 through 5,
respectively.



The Connection Points for Units 1 through 5 are in the BC Cobb Plant Substation (see Wiring Diagram
#240, Sheet 31 attached).



The Points of Receipt for all the Units in the Cobb Generating Plant Complex are deemed to be the
respective Connection Points.



Consumers’ Interconnection Assets



Consumers owns the following assets at the BC Cobb Plant Substation (Wiring Diagram #240, Sheet
31):




	 	 	 

	Transformer Banks

	 	Nos. 1, 2, 3, 4, 5, 7 and 8
	 
	Capacitor Banks

	 	Nos. 1 and 2
	 
	Circuit Breakers

	 	Nos. 100, 188, 199, 288, 299, 399,499, 599, 766, 799, 866, 899, 1177,
1188,1288, 1388, 1488 and 1688
	 
	Switches

	 	Nos. 100,102,104, 152, 156, 184, 185, 186,193,195, 196, 200, 252,
256,284, 285, 286, 293, 295, 296, 393, 395, 396, 493, 495,496, 593,
595, and 596, 709, 762, 764, 765, 793, 795, 796, 809, 862, 864, 865,
893,895,896, 1171, 1173, 1175, 1182,1184, 1185, 1282, 1284, 1285,
1323,1382, 1384,1385,1482,1484, 1485,1588, 1682,1684, 1685,
1788,1888, 2333, 7732-1, 8826-2 and 8832-2
	 
	Circuit Connections

	 	All wire, cable or buswork electrically connecting the switches identified
above to the Circuit Breakers identified above and to the main buswork.
	 
	Relay & Controls

	 	All relays and controls associated with the Circuit Breakers identified above
	 
	Foundations

	 	All foundations supporting the Transformers and Circuit Breakers identified above
	 
	Auxiliary Power

	 	All 2400 Volt station power assets shown in the attached Wiring Diagram #240





Transmission Owner Interconnection Assets



Transmission Owner owns the following assets at the BC Cobb Plant Substation (Wiring Diagram #240,
Sheet 31):




	 	 	 

	Circuit Breakers

	 	Nos. 148, 377, 488, 500, 588, 688, 788, 888 and 988
	 
	Switches

	 	Nos. 144, 145, 146, 307, 373, 375, 376, 408, 484, 485,486, 505,506,
508, 584, 585, 586, 608, 684, 685, 686, 708, 784, 785, 786, 808, 884,
885, 886, 908, 984, 985, 986, 1020,1021, 2030 and 2131
	 
	Circuit Connections

	 	All wire, cable or buswork electrically connecting the switches identified
above to the Circuit Breakers identified above and to the main buswork.
	 
	Relay & Controls

	 	All relays and controls associated with the Circuit Breakers identified above






 









 






Original Sheet No. 43




	 	 	 

	Foundations

	 	All foundations supporting the Circuit Breakers identified above





Jointly Owned Assets — Percentage Split by Major Equipment Count



Cobb Plant Substation -See Exhibit B — Table 1





 









 








Original Sheet No. 44




CEII MATERIAL





 











 






Original Sheet No. 45




Gaylord Generating Plant Complex



The Gaylord Generating Plant Complex consists of five combustion turbine generating Units, known as
Units 1 through 5, respectively.



The Connection Points for Units 1 through 5 are in the Gaylord Generating Substation (see Wiring
Diagram #495, Sheet 31 attached).



The Points of Receipt for all the Units in the Gaylord Generating Plant Complex are deemed to be
the respective Connection Points.



Consumers’ Interconnection Assets



Consumers owns the following assets at the Gaylord Generating Substation (Wiring Diagram #495,
Sheet 31):




	 	 	 
	Transformer Banks

	 	Nos. 1, 2* and 3* (*located outside of substation; not included in JOA calc)
	 
	 	 
	Circuit Breakers

	 	Nos. A16*, 116*, 146, 166, 199, 216*, 316*, 416* and 1288 (*located outside of substation; not included in JOA calc)
	 
	 	 
	Switches

	 	Nos. 3, 142, 144, 145, 162, 164, 165, 191, 193, 195, 299, 399, 1282 and 1284
	 
	 	 
	Circuit Connections

	 	All wire, cable or buswork electrically connecting the switches identified above to the Circuit Breakers identified above
	 
	 	 
	Relay & Controls

	 	All relays and controls associated with the Circuit Breakers identified above
	 
	 	 
	Foundations

	 	All foundations supporting the Transformers and Circuit Breakers identified above
	 
	 	 
	Auxiliary Power

	 	All station power assets shown in the attached Wiring Diagram #495, Sheet 31





Transmission Owner Interconnection Assets



Transmission Owner owns the following assets at the Gaylord Generating Substation (Wiring Diagram #495, Sheet 31):




	 	 	 
	Capacitor Bank

	 	No. 3
	 
	 	 
	Circuit Breakers

	 	Nos. 356, 377 and 477
	 
	 	 
	Switches

	 	Nos. 352, 371, 373, 375. 382, 384, 385, 471, 473, 475, 671, 673 and 675
	 
	 	 
	Circuit Connections

	 	All wire, cable or buswork electrically connecting the switches identified above to the Circuit Breakers identified above
	 
	 	 
	Relay & Controls

	 	All relays and controls associated with the Circuit Breakers identified above
	 
	 	 
	Foundations

	 	All foundations supporting the Circuit Breakers identified above










 









 








Original Sheet No. 46



Jointly Owned Assets — Percentage Split by Major Equipment Count



Gaylord Generating Substation — See Exhibit B — Table 1





 









 








Original Sheet No. 47




CEII MATERIAL








 









 








Original Sheet No. 48




Karn Generating Plant Complex



The Karn Generating Plant Complex consists of four generating Units, known as Units 1 (consisting
of generators 1A and 1B), Unit 2 (consisting of generators 2A and 2B, Unit 3 and Unit 4.



The Connection Point for Units 1 and 2 are in the DE Karn Plant 138 kV Substation (see Wiring
Diagram #695, Sheet 31 attached). The Connection Point for Units 3 and 4 are in the Hampton 345 kV
Substation (see Wiring Diagram #1327, Sheet 31 attached).



The Points of Receipt for all the Units in the DE Karn Generating Plant Complex are deemed to be
the respective Connection Points.



Consumers’ Interconnection Assets



Consumers owns the following assets at the DE Karn 138 kV Substation (Wiring Diagram #695, Sheet
31):




	 	 	 
	Transformer Banks

	 	Nos. 1 and 2 (located outside the substation; not included in JOA calc)
	 
	 	 
	Circuit Breakers

	 	Nos. 199, 299, 799 and 899
	 
	 	 
	Switches

	 	Nos. 136A, 136B, 195, 196, 236A, 236B, 295, 296, 793, 795, 796, 893, 895, and 896
	 
	 	 
	Circuit Connections

	 	All wire, cable or buswork electrically connecting the switches identified above to the Circuit Breakers identified above and to the main or transfer buswork
	 
	 	 
	Relay & Controls

	 	All relays and controls associated with the Circuit Breakers identified above
	 
	 	 
	Foundations

	 	All foundations supporting the Circuit Breakers identified above
	 
	 	 
	Auxiliary Power

	 	All 480 Volt and 4160 Volt station power assets shown in the attached Wiring Diagram #695, Sheet 31





Transmission Owner’s Interconnection Assets



Transmission Owner owns the following assets at the DE Karn 138 kV Substation (Wiring Diagram #695,
Sheet 31):




	 	 	 
	Circuit Breakers

	 	Nos. 148, 188, 388, 488, 500, 588 and 988
	 
	 	 
	Switches

	 	Nos. 108, 144,145, 146, 184,185, 186, 308, 384, 385, 386,408,484, 485,486, 505, 506, 508, 584, 585, 586, 709, 809, 908, 984, 985, 986, 2038 and 2131
	 
	 	 
	Circuit Connections

	 	All wire, cable or buswork electrically connecting the switches identified above to the Circuit Breakers identified above and to adjacent buswork
	 
	 	 
	Relay & Controls

	 	All relays and controls associated with the Circuit Breakers identified above
	 
	 	 
	Foundations

	 	All foundations supporting the Circuit Breakers identified above





Jointly Owned Assets — Percentage Split by Major Equipment Count



Karn Plant Substation -
See Exhibit B — Table 1








 









 








Original Sheet No. 49




CEII MATERIAL








 









 








Original Sheet No. 50




CEII MATERIAL








 









 








Original Sheet No. 51




Ludington Pumped Storage Generating Plant Complex



Note: The Detroit Edison Company has a overall 49% ownership interest in the Ludington Generating
Plant and certain other related facilities and property.



The Ludington Pumped Storage Generating Plant Complex consists of six motor-generator Units, known
as Units 1 through 6, respectively.



The Connection Points for Units 1 through 6 are in the Ludington Substation (see Wiring Diagram
#1405, Sheet 31 attached).



The Points of Receipt for all the Units in the Ludington Pumped Storage Generating Plant Complex
are deemed to be the respective Connection Points.



Generator Interconnection Assets



Consumers Energy and Detroit Edison, as noted above, share ownership of the following assets at the
Ludington Site (Wiring Diagram #1405, Sheet 31):




	 	 	 
	Transformer Banks

	 	Nos. 1,2, and 3 (located outside the substation; not included in JOA calc)
	 
	 	 
	Reactors

	 	Nos. 1 and 2 (located outside the substation; not included in JOA calc)
	 
	 	 
	Circuit Breakers

	 	Nos. 115, 116, 216, 316, 416 516, 615 and 616 (all phase-reversing 3-pole breakers associated with the motor-generators) and Nos. 1116 and 6116 (breakers associated with Pony Motors Nos. 1 and 2) (located outside the substation; not included in JOA calc)
	 
	 	 
	Switches

	 	Nos. 105, 215, 315, 415, 515, 1099, 1112 and 6112
	 
	 	 
	Removable Links

	 	Nos. 111, 112, 113, 212, 213, 312, 313, 412, 413, 512, 513, 612 and 613
	 
	 	 
	Circuit Connections

	 	All 345 kV conductors connecting the 20/345 kV Transformer Banks to the 345 kV buswork in the Ludington Substation All wire, cable or buswork electrically connecting the switches identified above to the Circuit Breakers identified above and to the 20
kV main and starting buswork
	 
	 	 
	Relay & Controls

	 	All relays and controls associated with the Circuit Breakers identified above
	 
	 	 
	Foundations

	 	All foundations supporting the Transformers and Circuit Breakers identified above
	 
	 	 
	Auxiliary Power

	 	All 480 Volt and 4160 Volt station power assets shown in the attached Wiring Diagram #1405, Sheet 31





Transmission Owner’s Interconnection Assets



Transmission Owner and Third Party share ownership of the following assets at the Ludington
Substation (Wiring Diagram #1405, Sheet 31):




	 	 	 
	Reactors

	 	Nos. 21 and 23
	 
	 	 
	Circuit Breakers

	 	Nos. 21F7, 21R8, 22F7, 22H9, 22R8, 23F7, 23R8, 24F7, 24H9, 24R8, 25F7, 25H9*, 25R8*, 26F7 and 26R8










 









 








Original Sheet No. 52




	 	 	 
	Switches

	 	Nos. 21F1, 21F3, 21R2, 21R4, 2156, 22F1,22F3, 22H5, 22H6, 22R2, 22R4,
23F1, 23F3, 23R2, 23R4, 2356, 24F1, 24F3, 24H5, 24H6, 24R2, 24R4, 25F1, 25F3, 25H5*, 25H6*, 25R2*, 25R4*,
26F1, 26H6, 26R2, and 26R4
	 
	 	 
	Circuit Connections

	 	All 345 kV conductors connecting the 20/345 kV Transformer Banks to the 345 kV buswork in the Ludington Substation All wire, cable or buswork electrically connecting the switches identified above to the Circuit Breakers identified above and to the 20 kV main and starting buswork
	 
	 	 
	Relay & Controls

	 	All relays and controls associated with the Circuit Breakers identified above
	 
	 	 
	Foundations

	 	All foundations supporting the Circuit Breakers identified above








 




			
	*	 	100% owned by Transmission Owner





	 	 	 
	Jointly Owned Assets -

	 	Percentage Split by Major Equipment Count
	 
	 	 
	Ludington Substation -

	 	Consumers (generation) = 0.00%; Consumers (distribution) = 0.00%;
	 

	 	Transmission Owner = 56.76%; Third Parties = 43.24%










 









 








Original Sheet No. 53




CEII MATERIAL











 









 








Original Sheet No. 54




Morrow Generating Plant Complex



The Morrow Generating Plant Complex consists of two combustion turbine generating Units, known as
Units A and B.



The Connection Points for both Units A and B are in the Morrow Substation (see Wiring Diagram #190,
Sheet 31, attached).



The Points of Receipt for the Units in the Morrow Generating Plant Complex are deemed to be the
Connection Points.



Consumers’ Interconnection Assets



Consumers owns the following assets at the Morrow Substation (Wiring Diagram #190, Sheet 31):




	 	 	 
	Transformer Banks

	 	No. 1, 2, 4 and 5
	 
	 	 
	Circuit Breakers

	 	Nos. 100, 156, 166, 199, 256, 266, 288, 299, 566, 499, 16A, 16B, 599, 1077, 1188, 1388,
1488, 1588, 1688 and 1788
	 
	 	 
	Switches

	 	Nos. 102, 104, 109, 162, 164, 165, 191, 193, 195, 196, 208, 209, 252, 262, 264,
265, 282, 284, 285, 286, 291, 293, 295,
296, 300, 495, 496, 509, 562, 564, 565, 591, 593, 595, 596, 1071, 1073, 1075, 1182, 1184, 1185, 1323, 1382, 1384, 1385,
1482, 1484, 1485, 1582, 1584, 1585, 1682, 1684, 1685, 1782, 1784, 1785 and 2333
	 
	Capacitors

	 	Nos. 1 and 2
	 
	 	 
	Circuit Connections

	 	All wire, cable or buswork electrically connecting the Transformers, Circuit Breakers and Switches identified above
	 
	 	 
	Relay & Controls

	 	All relays and controls associated with the Circuit Breakers identified above
	 
	 	 
	Foundations

	 	All foundations supporting the Transformers and Circuit Breakers identified above
	 
	 	 
	Auxiliary Power

	 	All 480 Volt station power assets shown in the attached Wiring Diagram #190, Sheet 31





Transmission Owner Interconnection Assets



Transmission Owner owns the following assets at the Morrow Substation (Wiring Diagram #190, Sheet
31):




	 	 	 
	Circuit Breakers

	 	Nos. 177, 377, 388, 500, 588, 677 and 988
	 
	 	 
	Switches

	 	Nos. 107, 173, 175, 176, 307, 308, 371, 373, 375, 376, 382, 384, 385, 386, 501, 502, 503, 504, 505, 506, 508, 582, 584, 585, 586, 607, 671, 673, 675, 676, 908, 982, 984, 985 and 986
	 
	 	 
	Circuit Connections

	 	All wire, cable or buswork electrically connecting the Circuit Breakers and Switches identified above
	 
	 	 
	Relay and Controls

	 	All relays and controls associated with the Circuit Breakers identified above
	 
	 	 
	Foundations

	 	All foundations supporting the Circuit Breakers identified above














 









 








Original Sheet No. 55



Third Party Owned Assets



Kalamazoo River Generation Station owns the following assets at the Morrow Substation (Wiring Diagram #190):




	 	 	 
	Circuit Breaker

	 	No. 888
	 
	Switches

	 	Nos. 882, 884, 885 and 886





Jointly Owned Assets — Percentage Split by Major Equipment Count



Morrow Substation — See Exhibit B — Table 1






 









 








Original Sheet No. 56




CEII MATERIAL





 











 





Original Sheet No. 57




Thetford Generating Plant Complex



The Thetford Generating Plant Complex consists of nine combustion turbine generating
Units, known as Units 1 through 9, respectively.



The Connection Points for Units 1 through 9 are in the Thetford Substation (see
Wiring Diagram #1000, Sheet 31 attached).



The Points of Receipt for all the Thetford Units are deemed to be the respective
Connection Points.



Consumers’ Interconnection Assets



Consumers owns the following assets at the Thetford Substation (Wiring Diagram #1000,
Sheet 31):




	 	 	 

	Transformer Banks

	 	Nos. 5, 6-1, 6-2 and 7
	 
	Circuit Breakers

	 	Nos. 13B7, 13W8, 116, 216, 316, 416, 516, 616, 716, 816 and 916
	 
	Switches

	 	Nos. 13B1, 13B3, 13M5, 13W2, 13W4, 591, 691-1, 691-2 and 791
	 
	Circuit
Connections

	 	All wire, cable or buswork electrically connecting the Transformer Banks, Circuit
Breakers and Switches identified above
	 
	Relay & Controls

	 	All relays and controls associated with the Circuit Breakers identified above
	 
	Foundations

	 	All foundations supporting the Transformers and Circuit Breakers identified
above





Transmission Owner Interconnection Assets



Transmission Owner owns the following assets at the Thetford Substation (Wiring Diagram
#1000, Sheet #31):




	 	 	 

	Transformer Banks

	 	Nos. 3 and 4
	 
	Circuit Breakers

	 	Nos. 6B7, 6M9, 6W8, 7B7, 7M9, 7W8, 9B7, 9M9, 9W8, 11B7, 11M9,
11W8, 27F7, 27H9, 27R8, 31F7, 31H9, 31R8, 33F7, 33H9 and 33R8
	 
	Switches

	 	Nos. 6B1, 6B3, 6M5, 6M6, 6W2, 6W4, 7B1, 7B3, 7M5, 7M6, 7W2, 7W4,
9B1, 9B3, 9M5, 9M6, 9W2, 9W4, 11B1 , 11B3, 11M5, 11M6, 11W2,
11W4, 27F1, 27F3, 27H5, 27H6, 27R2, 27R4, 31F1, 31F3, 31H5, 31H6,
31R2, 31R4, 33F1 , 33F3, 33H5, 33H6, 33R2, 33R4 and 35R2
	 
	Circuit Connections

	 	All wire, cable or buswork electrically connecting the Transformer Banks, Circuit
Breakers and Switches identified above
	 
	Relay and Controls

	 	All relays and controls associated with the Circuit Breakers identified above
	 
	Foundations

	 	All foundations supporting the Transformers and Circuit Breakers identified
above





Jointly Owned Assets — Percentage Split by Major Equipment Count


Thetford Substation — See Exhibit B — Table 1








 









 








Original Sheet No. 58




CEII MATERIAL




 









 





Original Sheet No. 59




Weadock Generating Plant Complex



The Weadock Generating Plant Complex consists of three generating
Units, known as Units 7, 8 and A.



The Connection Points for Units 7, 8 and A1 are in the John C Weadock
Substation (see Wiring Diagram #195, Sheet 31 attached). These Units are
currently in service. In addition, there are six other units, known as
Units 1 through 6, which have been retired from service, but are still in
place. Those assets are also described below, should the Units be
restored to service in the future.



The Points of Receipt for all the Units currently in service at the
Weadock Generating Plant Complex are deemed
to be the respective Connection Points.



Consumers’ Interconnection Assets (for Units In Service)



Consumers owns the following assets at the John C Weadock Substation
(Wiring Diagram #195, Sheets 2 and 31):




	 	 	 

	Transformer Banks

	 	Nos. 1, 2, 7, 8, 9 and 10
	 
	Circuit Breakers

	 	Nos. 66A, 100, 136, 166, 199, 236, 266, 299, 300, 736C, 799, 899, 966,
999, 1066, 1088, 1099, 1188, 1288 and 1388
	 
	Switches

	 	Nos. 62A, 64A, 102, 104, 105, 106, 132, 134, 135, 152, 156, 162, 164,
165, 195, 196, 200, 232, 234, 235, 252, 256, 262, 264, 265, 295, 296,
302, 304, 306, 400, 732C, 734C, 735C, 736A, 736B, 795, 796, 836A,
836B, 895, 896, 962, 964, 965, 991, 993, 995, 996, 1062, 1064, 1065,
1082, 1084, 1085, 1091, 1093, 1095, 1096, 1182, 1184, 1185, 1282,
1284, 1285, 1382, 1384 and 1385
	 
	Capacitors

	 	1 and 2
	 
	Circuit
Connections

	 	All wire, cable or buswork electrically connecting the Switches identified above
to the Circuit Breakers identified above and to the main buswork.
	 
	Relay & Controls

	 	All relays and controls associated with the Circuit Breakers identified above
	 
	Foundations

	 	All foundations supporting the Transformer Banks and Circuit Breakers identified
above
	 
	Auxiliary Power

	 	All 480 Volt and 4160 Volt station power assets shown in the attached Wiring
Diagram #195, Sheet 31





Consumers’ Interconnection Assets (for Units Retired in Place)



Consumers owns the following assets at the John C Weadock Substation
(Wiring Diagram #195, Sheet 31):




	 	 	 

	Transformer Banks

	 	Nos. 5 and 6
	 
	Circuit Breakers

	 	Nos. 99A, 116, 216, 316, 336, 416 and 436
	 
	Switches

	 	Nos. 93A, 112, 114, 212, 214, 312, 314,
332, 412, 414, 432, 516, 536
and 616
	 
	Circuit
Connections

	 	All wire, cable or buswork electrically
connecting the Switches identified above to the
Circuit Breakers identified above and to the main
buswork.






 









 






Original Sheet No. 60




	 	 	 

	Relay & Controls

	 	All relays and controls
associated with the Circuit Breakers
identified above
	 
	Foundations

	 	All foundations supporting the
Transformer Banks and Circuit Breakers
identified above





Transmission Owner Interconnection Assets



Transmission Owner owns the following assets at the John C Weadock
Substation (Wiring Diagram #195, Sheet 31):




	 	 	 

	Circuit Breakers

	 	Nos. 148, 188, 288, 388, 488, 500, 588, 688 and 788
	 
	Switches

	 	Nos. 108, 142, 144, 145, 146, 182, 184, 185, 186, 208, 282, 284, 285,
286, 308, 382, 284, 385, 386, 408, 482, 484, 485, 486, 505, 506, 508,
582, 584, 585, 586, 608, 682, 684, 685, 686, 708, 782, 784, 785, 786,
900, 1020,1121, 2030, 2131, 3040, 3141, 4050 and 4151
	 
	Circuit
Connections

	 	All wire, cable or buswork electrically connecting the Switches identified above
to the Circuit Breakers identified above and to the main buswork
	 
	Relay & Controls

	 	All relays and controls associated with the Circuit Breakers identified above
	 
	Foundations

	 	All foundations supporting the Circuit Breakers identified above





Jointly
Owned Assets
 — Percentage Split
by Major Equipment
Count



John C
Weadock Substation
 — See Exhibit B -
Table 1





 









 








Original Sheet No. 61




CEII MATERIAL




 









 






Original Sheet No. 62




Whiting Generating Plant Complex



The Whiting Generating Plant Complex consists of four generating Units, known
as Units 1, 2, 3 and A.



The Connection Points for Units 1, 2, 3 and A are in the Whiting Substation (see
Wiring Diagram #400, Sheet 31 attached). Units 1, 2 and 3 are connected to the 138
kV buswork and Unit A is connected to the 46 kV buswork



The Points of Receipt for all the Units in the Whiting Generating Plant Complex are
deemed to be the respective Connection Points.



Consumers’ Interconnection Assets



Consumers owns the following assets at the Whiting Substation (Wiring Diagram #400,
Sheet 31):




	 	 	 

	Transformer Banks

	 	Nos. 1, 2, 3, 7 and A
(TB # A located outside of
substation; not included in
JOA calc)
	 
	Circuit Breakers

	 	Nos. 16A (located
outside switchyard; not
included in JOA calc), 46A,
199, 299, 399, 766, 799,
1188 and 1288
	 
	Switches

	 	Nos. 42A, 44A, 45A,
99A, 105, 156, 191, 193,
195, 196, 291, 293, 295,
296, 391, 393, 395, 396,
79T1, 762, 764, 765, 795,
796, 1182, 1184,
1185, 1282, 1284, 1285
	 
	Capacitor Bank

	 	No 1
	 
	Circuit Connections

	 	All wire, cable or
buswork electrically
connecting the Transformer
Banks, Circuit Breakers and
Switches identified above to
each other, as appropriate,
to the main buswork and to
the Auxiliary Power
assets
	 
	Relay & Controls

	 	All relays and controls
associated with the Circuit
Breakers identified
above
	 
	Foundations

	 	All foundations
supporting the Transformer
Banks and Circuit Breakers
identified above
	 
	Auxiliary Power

	 	All 480 Volt and 2400
Volt station power assets
shown in the attached Wiring
Diagram #400, Sheet 31





Transmission Owner
Interconnection Assets



Transmission Owner owns the following assets at the Whiting Substation
(Wiring Diagram #400, Sheet 31):




	 	 	 

	Transformer Bank

	 	No. 8
	 
	Circuit Breakers

	 	Nos. 500, 688, 788,899 and 988
	 
	Switches

	 	Nos. 501, 502, 503, 504, 505, 506, 608, 682,
684, 685, 686, 785, 786,
866, 895, 896, 908, 982, 984, 985 and 986
	 
	Circuit
Connections

	 	All wire, cable or buswork electrically
connecting the Transformer Banks, Circuit Breakers
and Switches identified above to each other, as
appropriate, to the main buswork






 









 






Original Sheet No. 63




	 	 	 

	Relay & Controls

	 	All relays and controls associated
with the Circuit Breakers identified
above
	 
	Foundations

	 	All foundations supporting the
Transformer Bank and Circuit Breakers
identified above





Jointly Owned
Assets — Percentage Split by
Major Equipment Count



Whiting
Substation — See Exhibit B -
Table 1





 









 








Original Sheet No. 64




CEII MATERIAL




 









 





Original Sheet No. 65




EXHIBIT C



Generator Connections located in Consumers’ Distribution System



The following Units are connected indirectly to the Transmission System and do not have specific
connection data listed herein.





Alcona Hydro Generating Plant, Units 1 and 2  

Calkins Bridge “Allegan” Hydro Generating Plant, Units 1, 2 and 3  

Cooke Hydro Generating Plant, Units 1, 2 and 3  

Croton Hydro Generating Plant, Units 1, 2, 3 and 4 

Five Channels Generating Plant, Units 1 and 2  

Foote Hydro Generating Plant, Units 1, 2 and 3  

Hodenpyl Hydro Generating Plant, Units 1 and 2  

Loud Hydro Generating Plant, Units 1 and 2  

Mio Hydro Generating Plant, Units 1 and 2  

Rogers Hydro Generating Plant, Units 1, 2, 3 and 4

Straits Combustion Turbine Generating Unit 1  

Tippy Hydro Generating Plant, Units 1, 2 and 3  

Webber Hydro Generating Plant, Units 1 and 2





Consumers Energy Generator Connections Covered under Other Interconnection Agreements



The following Units are covered under their own LGIAs and do not have specific connection data
listed herein.



Campbell Generating Plant, Unit 3.



Hardy Hydro Generating Plant, Units 1, 2 and 3.



Zeeland Power Plant