Document:

EXHIBIT 10-35 
	 

	 
		Second Restated Partial
	 

	 
		Requirements Agreement
	 

	 
		This SECOND RESTATED PARTIAL REQUIREMENTS
		AGREEMENT (this “Agreement”), dated January 1, 2007, is entered into
		among Metropolitan Edison Company, a Pennsylvania corporation
		(“MetEd”), Pennsylvania Electric Company, a Pennsylvania
		corporation (“Penelec”),
		on behalf of itself and The Waverly Electric Power and Light Company, a New
		York corporation (“Waverly,”
		and together with MetEd and Penelec, “Buyers”),
		and FirstEnergy Solutions Corp., an Ohio corporation (“Seller”),
		all wholly owned subsidiaries of FirstEnergy Corp., an Ohio corporation. The
		Buyers and Seller may individually be referred to as a “Party” or
		collectively as “Parties” in
		this Agreement.
	 

	 
		WHEREAS, Buyers are electric distribution
		companies with an obligation to serve retail customers under New York and
		Pennsylvania law (hereinafter “Provider
		of Last Resort Obligation”);
	 

	 
		WHEREAS, Seller is authorized to sell
		wholesale capacity, energy, and ancillary services to Buyers under First
		Revised Service Agreements Nos. 1 and 2, effective June 1, 2002
		(“Service
		Agreements”), pursuant to
		Seller’s FERC Electric Tariff, Original Volume No. 1, and is
		authorized under the Service Agreements to require a “Confirmation
		Letter” to document transactions thereunder;
	 

	 
		WHEREAS, Buyers currently obtain from Seller
		some or all of the wholesale capacity and energy (such resources, the
		“Resources”) necessary to satisfy their retail Provider of
		Last Resort Obligation;
	 

	 
		WHEREAS, the Parties previously entered into
		a Restated Partial Requirements Agreement, dated January 1, 2003, among
		the Parties (as amended, modified or supplemented prior to the date hereof, the
		“Requirements
		Agreement”);
	 

	 
		WHEREAS, Buyers wish to amend the
		Requirements Agreement to allow them to engage in NUG Sales (as defined below)
		and to have Seller provide energy to replace energy sold in NUG Sales to the
		extent Buyers need replacement energy to satisfy their Provider of Last Resort
		Obligation; and
	 

	 
		WHEREAS, the Requirements Agreement is a
		“Confirmation Letter” as such term is used in the Services
		Agreements, and the Parties desire to amend and restate their obligations under
		the Requirements Agreement by entering this Agreement, which also constitutes a
		“Confirmation Letter” as such term is used in the Service
		Agreements.
	 

	 
		NOW THEREFORE, in consideration of the
		mutual agreements, covenants and conditions herein contained, and for other
		good and valuable consideration, the receipt and sufficiency of which are
		hereby acknowledged, and intending to be legally hound, Buyers and Seller
		hereby agree as follows:
	 

	 
		1. Purchase. Buyers
		agree to purchase Resources from Seller (such Resources, “Seller Resources”) to satisfy their Provider of Last Resort
		Obligation to the extent that Buyers
	 

	 
		 
	 

	 
		 
	 

	 
		2
	 

	 
		 
	 

	 
	 

	 

	 
		have a need for Resources in excess of
		Resources otherwise committed or available to satisfy such obligation (such
		committed or available Resources, “Committed Resources”). For purposes of this Agreement, Committed
		Resources include, but are not limited to, Resources produced by or pursuant to
		non-utility generation under contract to Buyers (“NUG Generation”), Buyer-owned generating facilities, existing or
		new purchased power contracts with persons other than Seller (including
		capacity, energy and related services obtained by Seller as agent for Buyers),
		and distributed generation.
	 

	 
		2. Agency. Buyers
		may authorize Seller to act as agent for Buyers in obtaining capacity, energy
		and related services on Buyers’ behalf when the Parties agree that such
		capacity, energy and related services are reasonable and economic. Buyers shall
		authorize Seller to act as agent by giving Notice to Seller of such
		authorization, including its scope and duration.
	 

	 
		3. Sale.
	 

	 
		(a) Seller agrees to supply Resources not to
		exceed the total Resources required to meet the Buyers’ Provider of Last
		Resort Obligation, less any Committed Resources used to satisfy such Provider
		of Last Resort Obligation, on the terms and conditions set forth in this
		Agreement, and will comply with all requirements of the Federal Energy
		Regulatory Commission (“FERC”), the
		New York Public Service Commission and the Pennsylvania Public Utility
		Commission and with the applicable requirements of PJM Interconnection, LLC
		(“PJM”) in supplying Seller Resources.
	 

	 
		(b) If a Buyer gives Notice to Seller that
		the Buyer intends to sell NUG Generation to third parties other than pursuant
		to the Buyer’s Provider of Last Resort Obligation (such sales,
		“NUG Sales”) at least 10 business days prior to the first
		such NUG Sale and if Seller does not object in writing to such NUG Sales within
		5 business days of receiving the Buyer’s Notice, (i) the Buyer may
		engage in the NUG Sales described in the Buyer’s Notice; and
		(ii) such NUG Sales shall be excluded from the calculation of Committed
		Resources used to satisfy the Buyer’s Provider of Last Resort Obligation,
		and Seller shall provide replacement energy required by the Buyer;
		provided, that Seller shall not be responsible for supplying
		capacity or capacity credits to replace any capacity or capacity credits sold
		by the Buyer as part of its NUG Saks.
	 

	 
		4. Forecast of Provider of Last Resort Obligation and
		Committed Resources. No later than
		sixty days prior to the beginning of any calendar year, Buyers shall provide
		Seller a forecast (“Annual
		Forecast”) of the Resources
		necessary to satisfy their Provider of Last Resort Obligation, the Seller
		Resources to be purchased and their Committed Resources for that calendar year.
		The Annual Forecast will be provided in the format and detail agreed upon by
		the Parties. Buyers will update the Annual Forecast no less frequently than
		monthly for known changes, including but not limited to the changes described
		in Section 3(b).
	 

	 
		5. (a) Delivery Points.
		Seller shall inform Buyers telephonically by 8:00 A.M. East Coast time each day
		on which Seller Resources are scheduled to be sold to Buyers within the
		following twenty-four (24) hour period of the points at which Seller shall
		deliver Seller Resources to Buyers (such points, the “Delivery Points”).
	 

	 
		 
	 

	 
		 
	 

	 
		3
	 

	 
		 
	 

	 
	 

	 

	 
		(b) Transfer of Title; Transmission and
		Scheduling. Title and risk of loss for
		Seller Resources shall pass to Buyers at the Delivery Points. Seller shall sell
		and deliver, or cause to be delivered, and Buyers shall purchase and receive,
		or cause to be received, Seller Resources at the Delivery Points. Seller shall
		be responsible for any costs or charges imposed on or associated with Seller
		Resources or their delivery up to the Delivery Points, including any costs or
		charges associated with transmission service or scheduling services. Buyers
		shall be responsible for any costs or charges imposed on or associated with
		Seller Resources or their receipt at and from the Delivery Points, including
		any costs or charges associated with transmission service or scheduling
		services.
	 

	 
		6. Price for Provider of Last Resort
		Service.
	 

	 
		(a) Direct Sales.
		MetEd and Penelec shall pay Seller $41.65 and $41.41 per megawatt-hour,
		respectively, for all Seller Resources. The Parties will agree upon a transfer
		date for the funds remitted to Seller that will be no less frequently than
		monthly.
	 

	 
		(b) Procurement as Agent. Buyers shall reimburse Seller for all costs, charges
		and fees Seller incurs in procuring Committed Resources on Buyers’ behalf
		under Section 2 of this Agreement. For the avoidance of doubt, Seller
		shall not charge Buyers any mark-up, profit fee, or commission for
		Seller’s services in procuring Committed Resources pursuant to
		Section 2 of this Agreement.
	 

	 
		7. Other Services Provided by Seller. Subject to receiving any necessary approvals or
		waivers from FERC, (a) Seller may provide Buyers technical advice and
		assistance and other services as may be reasonably necessary to assist Seller
		in minimizing its costs of providing Seller Resources, such services including
		but not limited to price forecasting, risk management advice, management of
		congestion costs and related services, and (b) Buyers shall provide Seller
		with data necessary to perform such services. No fee or charges in addition to
		those imposed by other terms of this Agreement shall be imposed for services
		provided by Seller pursuant to this Section 7.
	 

	 
		8. Effective Date and Term. This Agreement shall be effective January 1, 2007
		and will remain in effect until December 31, 2007. This initial term will
		be automatically extended for successive periods of one year unless any Party
		gives sixty days’ notice of termination to the other Parties prior to the
		end of the calendar year then in effect. Unless otherwise agreed by the
		Parties, such termination shall not affect or excuse the performance of
		transactions entered into on behalf of either Party prior to notice of
		termination. This Agreement shall remain in effect until both Parties have
		fully performed their obligations under said transactions.
	 

	 
		9. Regulatory Out Termination. In the event that a Party’s obligations under
		this Agreement are materially and adversely affected by a change in law, rule,
		regulation, or other action by a governmental authority or regulatory agency,
		the adversely affected Party may terminate this Agreement upon sixty days’
		written notice to the other Party.
	 

	 
		10. Governing Law.
		This Agreement shall be governed by and construed in accordance with the laws
		of the Commonwealth of Pennsylvania without regard to the choice of law rules
		thereof.
	 

	 
		 
	 

	 
		 
	 

	 
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		11. Execution in Counterparts; Facsimile
		Signatures. This Agreement may be
		executed in multiple counterparts, each of which shall be considered an
		original instrument, but all of which shall be considered one and the same
		agreement, and shall become binding when all counterparts have been signed by
		each of the Parties and delivered to each Party hereto. Delivery of an executed
		signature page counterpart by telecopies or e-mail shall be as effective as
		delivery of a manually executed counterpart.
	 

	 
		12. Representation and Warranties. Each Party represents and warrants that it has full
		authority and right to enter into this Agreement.
	 

	 
		13. Effect of Agreement. This Agreement supersedes and replaces all prior
		agreements among the Parties with respect to the subject matter hereof,
		including the Requirements Agreement, that certain Notice of Termination
		Tolling Agreement dated November 1, 2005 among the Parties, and that
		certain Notice of Termination Tolling Agreement dated April 7, 2006 among
		the Parties.
	 

	 
		14. Notice. All
		notices and other communications under this Agreement (“Notices”)
		shall be in writing and shall be deemed duly given (a) when delivered
		personally or by prepaid overnight courier, with a record of receipt,
		(b) the fourth day after mailing if mailed by certified mail, return
		receipt requested, or (c) the day of transmission, if sent by facsimile,
		telecopy or e-mail (with a copy promptly sent by prepaid overnight courier with
		record of receipt or by certified mail, return receipt requested), to the
		Parties at the following addresses or telecopy numbers (or to such other
		address or telecopy number as a Party may have specified by notice given to the
		other Parties pursuant to this provision):
	 

	 
		If to Buyers:
	 

	 
		Dean W. Stathis
	 

	 
		2800 Pottsville Pike
	 

	 
		P.O. Box 16001
	 

	 
		Reading, PA 19612
	 

	 
		Email:
		    dstathis@firstenergycorp.com
	 

	 
		Tel. No.:  (610) 921-6766
	 

	 
		Fax No.:  (610) 939-8542
	 

	 
		with copies (which shall not constitute
		Notice) to:
	 

	 
		Linda R. Evers, Esq.
	 

	 
		2800 Pottsville Pike
	 

	 
		P.O. Box 16001
	 

	 
		Reading, PA 19612
	 

	 
		Email:
		    levers@firstenergycorp.com
	 

	 
		Tel. No.: (610) 921-6658
	 

	 
		Fax No.: (610) 939-8655
	 

	 
		 
	 

	 
		 
	 

	 
		5
	 

	 
		 
	 

	 
	 

	 

	 
		If to Seller:
	 

	 
		FirstEnergy Solutions Corp.
	 

	 
		395 Ghent Road
	 

	 
		Akron, OH 44333
	 

	 
		Attention: Lisa Medas
	 

	 
		Email
		      lamedas@fes.com
	 

	 
		Tel. No.:  (330) 315-6848
	 

	 
		Fax No.:  (330) 315-7266
	 

	 
		with a copy (which shall not constitute
		Notice) to:
	 

	 
		Michael Beiting, Esq.
	 

	 
		FirstEnergy Corp.
	 

	 
		76 South Main Street
	 

	 
		Akron, OH 44308
	 

	 
		Email:
		    beitingm@firstenergycorp.com
	 

	 
		Tel. No.: (330) 384-5795
	 

	 
		Fax No.: (330) 384-3875
	 

	 
		[Signature pages follow]
	 

	 
		 
	 

	 
		 
	 

	 
		6
	 

	 
		 
	 

	 
	 

	 

	 
		IN WITNESS WHEREOF, this Agreement has been
		executed and delivered by the duly authorized officers of the Parties as of the
		date first above written.
	 

	 
		FirstEnergy Solutions Corp.
	 

	 
		 
	 

	 
			
				
				   
				

			 	
				
				   
				

			 	
				
				   
				

			 	
				
				   
				

			 	
				
				   
				

			 
	
				
				  By: 
				

			 	
				
				  /s/ Guy L. Pipitone
				

			 	
				
				   
				

			 	
				
				   
				

			 	
				
				   
				

			 
	
				
				   
				

			 	
				
				  Name: 
				

			 	

				
				  Guy L. Pipitone
				

			 	
				
				   
				

			 	
				
				   
				

			 	
				
				   
				

			 
	
				
				   
				

			 	
				
				  Title: 
				

			 	
				
				  President
				

			 	
				
				   
				

			 	
				
				   
				

			 	
				
				   
				

			 

 

	 
		 
	 

	 
		 
	 

	 
		[Signature Page to Second
		Restated
 Partial Requirements Agreement]
	 

	 
		 
	 

	 
		 
	 

	 
	 

	 

	 
		IN WITNESS WHEREOF, this Agreement has been
		executed and delivered by the duly authorized officers of the Parties as of the
		date first above written.
	 

	 
		Metropolitan Edison Company
	 

	 
		Pennsylvania Electric Company
	 

	 
		The Waverly Electric Power and Light
		Company
	 

	 
		 
	 

	 
			
				
				   
				

			 	
				
				   
				

			 	
				
				   
				

			 	
				
				   
				

			 	
				
				   
				

			 
	
				
				  By: 
				

			 	
				
				  /s/ Douglas S. Elliott
				

			 	
				
				   
				

			 	
				
				   
				

			 	
				
				   
				

			 
	
				
				   
				

			 	
				
				  Name: 
				

			 	

				
				  Douglas S. Elliott
				

			 	
				
				   
				

			 	
				
				   
				

			 	
				
				   
				

			 
	
				
				   
				

			 	
				
				  Title: 
				

			 	
				
				  President, Pennsylvania
				  Operations
				

			 	
				
				   
				

			 	
				
				   
				

			 	
				
				   
				

			 

 

	 
		 
	 

	 
		 
	 

	 
		[Signature Page to Second
		Restated
 Partial Requirements Agreement]EXHIBIT 10-36 
	 

	 
		FirstEnergy Generation Corp.
	 

	 
		FERC Electric Tariff, Original Volume No.
		1
	 

	 
		Second Revised Service Agreement No.
		2
	 

	 
		GENCO POWER SUPPLY AGREEMENT
	 

	 
		 
	 

	 
		Between FirstEnergy Generation Corp.,
		Seller
	 

	 
		and
	 

	 
		FirstEnergy Solutions Corp.,
		Buyer
	 

	 
		This Second Revised GENCO Power Supply
		Agreement (“Agreement”) dated January 1, 2007, is made by and between
		FirstEnergy Generation Corp., (“Genco” or “Seller”), and
		FirstEnergy Solutions Corp. (“Solutions” or “Buyer”). Genco
		and Solutions may be identified collectively as “Parties” or
		individually as a “Party.” This Agreement is entered into in
		connection with the transfer of ownership of The Cleveland Electric
		Illuminating Company, Ohio Edison Company, Pennsylvania Power Company, and The
		Toledo Edison Company’s fossil and pumped storage generation assets to
		Genco.
	 

	 
		WHEREAS, Seller is a generation only company
		that owns, operates and leases fossil and pumped storage generation assets;
		and
	 

	 
		WHEREAS, Seller is engaged in the business
		of owning and operating this generation and selling Power at wholesale,
		and
	 

	 
		WHEREAS, Seller is a wholly owned subsidiary
		of Solutions; and
	 

	 
		WHEREAS, Buyer desires to obtain the entire
		electric output of the generating plants owned, operated, leased or controlled
		by Genco as described in Exhibit C (collectively, the “Genco
		Facilities”), pursuant to the rates, terms and conditions set forth
		herein.
	 

	 
		It is agreed as follows:
	 

	 
			
				
				  I.
				

			 	
				
				  TERM
				

			 

 

	 
		The sale and purchase of Power pursuant to
		this Agreement shall begin on January 1, 2007, for an initial term ending
		December 31, 2010. This Agreement shall remain in effect from year to year
		thereafter unless terminated by either Party upon at least sixty days written
		notice prior to the end of the calendar year.
	 

	 
		 
	 

	 
			
				
				  Issued by: Ali Jamshidi,
				  President
				

			 	
				
				  Effective Date:
				

			 
	
				
				  Issued on: January 1, 2007
				

			 	
				
				  January 1, 2007
				

			 

 

	 
		 
	 

	 
		 
	 

	 
	 

	 

	 
			
				
				  II.
				

			 	
				
				  SALE AND PURCHASE OF CAPACITY AND
				  ENERGY
				

			 

 

	 
			
				
				  A.
				

			 	
				
				  Seller shall make available to Buyer
				  all of the Capacity, Energy, Ancillary Services, Emission Allowances, and
				  Renewable Energy Attributes, if any, which are available from the Genco
				  Facilities or as part of any other agreements in which Buyer and/or Seller have
				  ownership or control of the power supply and Buyer shall purchase and pay for
				  such Capacity, Energy, Ancillary Services, Emission Allowances and Renewable
				  Energy Attributes in accordance with the terms of this Agreement. Seller shall
				  make firm Capacity, Energy, and Ancillary Services available at the Delivery
				  Points. Buyer shall arrange and will be responsible for all transmission,
				  congestion costs, losses, and related services at and from the Delivery Points.
				  The Capacity, Energy, Ancillary Services, Emission Allowances and Renewable
				  Energy Attributes supplied by Seller are collectively referred to as
				  Buyer’s “Power Supply Requirements.” Electric Capacity and
				  Energy supplied shall be sixty-hertz, three phase alternating current. The
				  Power Supply Requirements will be provided in accordance with Good Utility
				  Practice, and where applicable, the provisions of the applicable Transmission
				  Provider OATT, and the requirements of the FERC.
				

			 

 

	 
			
				
				  B.
				

			 	
				
				  Genco will operate and maintain the
				  Genco Facilities in accordance with Good Utility Practice, the applicable
				  requirements of the FERC, NERC, Electric Reliability Organization, as well as
				  the requirements of the regional reliability councils or Regional Entity and
				  Regional Transmission Organizations where the Genco Facilities are
				  located.
				

			 

 

	 
			
				
				  C.
				

			 	
				
				  The Parties acknowledge that the
				  Genco Facilities identified in Exhibit C may change from time to time due to
				  changes in the generation facilities or generation output owned, operated,
				  leased, or otherwise controlled by Genco. Genco will provide , Solutions with
				  an updated Exhibit C reflecting such changes in Genco Facilities in. accordance
				  with the notification deadlines provided for in Article III below.
				  Seller’s obligation to sell and make the entire output of the Genco
				  Facilities available to Buyer, and Buyer’s obligation to take and pay for
				  the entire output of the Genco Facilities, will not be affected by changes in
				  Genco Facilities.
				

			 

 

	 
			
				
				  III.
				

			 	
				
				  SCHEDULING AND SYSTEM
				  PLANNING
				

			 

 

	 
			
				
				  A.
				

			 	
				
				  In order for Solutions to be able to
				  plan adequately to market and sell all of the Capacity, Energy, Ancillary
				  Services, Emission Allowances and Renewable Energy Attributes available from
				  the Genco Facilities, Genco shall notify Solutions on or before November 1 of
				  each year during the term of this Agreement of the amount of Capacity, Energy,
				  Ancillary Services, Emission Allowances and Renewable Energy Attributes it
				  expects to have available for each day in each month of the next calendar year.
				  The information provided in this notification shall include, but not be limited
				  to, the time and expected duration of any planned outage of the Genco
				  Facilities.
				

			 

 

	 
			
				
				  B.
				

			 	
				
				  Genco shall update its annual
				  forecast of available Capacity, Energy, Ancillary Services, Emission
				  Allowances, and Renewable Energy Attributes for any change or expected changed
				  in the operation of Genco Facilities that would materially affect the annual
				  forecast provided to Solutions. Genco shall provide the updated forecast to
				  Solutions for 
				

			 

 

	 
		 
	 

	 
	 

	 

	 
		any full month(s) remaining in the calendar
		year within thirty days of becoming aware of the change or expected change in
		the operation-of the Genco Facilities.
	 

	 
			
				
				  C.
				

			 	
				
				  Genco will supply Solutions, upon
				  request, any such information as is necessary to meet the requirements of the
				  applicable Transmission Provider OATT, the FERC, NERC, Electric Reliability
				  Organization, regional reliability council, Regional Entity or Government
				  Authority.
				

			 

 

	 
			
				
				  IV.
				

			 	
				
				  PRICE
				

			 

 

	 
		Seller shall charge, and Buyer shall pay,
		for Buyer’s Power Supply Requirements, as follows on a monthly
		basis.
	 

	 
		A. Charges
	 

	 
		Buyer will pay Seller the Monthly Charge
		under the formula set forth in Exhibit A for the Power Supply Requirements
		available from the Genco.Facilities identified in Exhibit C.
	 

	 
		B. Billing and Payment
	 

	 
		Unless otherwise specifically agreed upon by
		the Parties, the calendar month shall be the standard period for all billings
		and payments under this Agreement. As soon as practicable after the end of each
		month, the Seller will render an invoice to Buyer for the amounts due for Power
		Supply Requirements for the preceding month. Payment shall be due and payable
		within ten days of receipt of the invoice or, if such day is not a Business
		Day, then on the next Business Day. Buyer will make payments by electronic
		funds transfer or by other mutually agreeable method(s) to the account
		designated by Seller. Any amounts not paid by the due date will be deemed
		delinquent and will accrue interest at the Interest Rate until the date of
		payment in full.
	 

	 
		C. Records
	 

	 
		Each Party shall keep complete and accurate
		records of its operations under this Agreement and shall maintain such data as
		may be necessary to determine the reasonableness and accuracy of all relevant
		data, estimates, payments or invoices submitted by or to it hereunder. All
		records regarding this Agreement shall be maintained for a period of five years
		from the date of the invoice or payment, or for such longer period as may be
		required by law.
	 

	 
		D. Audit and Adjustment Rights
	 

	 
		Buyer shall have the right, at its own
		expense arid during normal business hours, to audit the accounts and records of
		Seller that reasonably relate to the provision of service under this Agreement.
		If the audit reveals an inaccuracy in an invoice, the necessary adjustment in
		such invoice and the payments therefor will be promptly made. No adjustment
		will be made for any invoice or payment made more than one year from rendition
		thereof. This provision shall survive the termination of this Agreement for a
		period of one year from the date of termination for the purpose of such invoice
		and payment objections. To the extent that audited information includes
		Confidential Information, the Buyer shall keep all such information
		confidential under Section VII.C.
	 

	 
		 
	 

	 
	 

	 

	 
		E. Section 205 Rights
	 

	 
		Nothing contained herein shall be construed
		as affecting in any way the right of the Party furnishing service under this
		Agreement to unilaterally make application to the FERC for a change in rates
		under Section 205 of the Federal Power Act and pursuant to the FERC’s
		Rules and Regulations thereunder. Provided, however, that nonrate terms and
		conditions may be amended only by a written agreement signed by the
		Parties.
	 

	 
			
				
				  V.
				

			 	
				
				  METERING
				

			 

 

	 
		Generation metering shall be installed,
		operated and maintained in accordance with the applicable generator
		interconnection agreements between the Genco, Transmission Provider, and
		Transmission Owner. Metering between control areas shall be handled in
		accordance with the applicable Transmission Provider OATT. Retail metering
		shall be provided in accordance with applicable state law. Nothing in this
		Agreement requires Seller or Buyer to install new metering facilities.
	 

	 
			
				
				  VI.
				

			 	
				
				  NOTICES
				

			 

 

	 
		All notices, requests; statements or
		payments shall be made as specified below. Notices required to be in writing
		shall be delivered by letter, facsimile or other documentary form. Notice by
		facsimile or hand delivery shall be deemed to have been received by the close
		of the Business Day on which it was transmitted or hand delivered (unless
		transmitted or hand delivered after close in which case it shall be deemed to
		have been received at the close of the next Business Day). Notice by- overnight
		mail or courier shall be deemed to have been received two Business Days after
		it was sent. A Party may change its addresses by giving notice as provided
		above.
	 

	 
		NOTICES & CORRESPONDENCE:
	 

	 
		 
	 

	 
			
				
				  To Seller:
				

			 	
				
				  FirstEnergy Generation Corp.,
				  President 76
 South Main St.

				  Akron, Ohio 44308
				

			 
	
				
				   
				

			 	
				
				   
				

			 
	
				
				  To Buyer:
				

			 	
				
				  FirstEnergy Solutions Corp.,
				  Director, Wholesale Energy Transactions
 395 Ghent Road
 Akron, Ohio 44333
				

			 
	
				
				   
				

			 	
				
				   
				

			 
	
				
				  INVOICES & PAYMENTS:
				

			 
	
				
				   
				

			 	
				
				   
				

			 
	
				
				  To Seller:
				

			 	
				
				  FirstEnergy Generation Corp.,
				  President
 76 South Main St.

				  Akron, Ohio 44308
				

			 
	
				
				   
				

			 	
				
				   
				

			 
	
				
				  To Buyer:
				

			 	
				
				  FirstEnergy Solutions Corp.,
				  Director, Wholesale Energy Transactions
 395 Ghent Road
 Akron, Ohio 44333
				

			 
	
				
				   
				

			 	
				
				   
				

			 
	
				
				  SCHEDULING:
				

			 

 

	 
		 
	 

	 
	 

	 

	 
		 
	 

	 
			
				
				  To Seller:
				

			 	
				
				  FirstEnergy Generation Corp.,
				  President
 76 South Main St.

				  Akron, Ohio 44308
				

			 
	
				
				   
				

			 	
				
				   
				

			 
	
				
				  To Buyer:
				

			 	
				
				  FirstEnergy Solutions Corp.,
				  Director, Wholesale Energy Transactions
 395 Ghent Road
 Akron, Ohio 44333
				

			 

 

	 
			
				
				  VII.
				

			 	
				
				  MISCELLANEOUS
				

			 

 

	 
		A. Performance Excused
	 

	 
		If either Party is rendered unable by an
		event of Force Majeure to carry out, in whole or part, its obligations
		hereunder, then, during the pendency of such Force Majeure but for no longer
		period, the Party affected by the event shall be relieved of its, obligations
		insofar as they are affected by Force Majeure. The Party affected by an event
		of Force Majeure shall provide the other Party with written notice setting
		forth the, full details thereof as soon as practicable after the occurrence of
		such event and shall take all reasonable measures to mitigate or minimize the
		effects of such event of Force Maj cure. Nothing in this Section requires
		Seller to deliver, or Buyer to receive, Power at Delivery Points other than
		those Delivery Points designated under this Agreement, or relieves Buyer of its
		obligation to make payment under Section IV of this Agreement.
	 

	 
		Force Majeure shall be defined as any cause
		beyond the reasonable control of, and not the result of negligence or the lack
		of diligence of, the Party claiming Force Majeure or its contractors or
		suppliers. It includes, without limitation, earthquake, storm,
		lightning,-flood, backwater caused by flood, fire, explosion, act of the public
		enemy, epidemic, accident, failure of facilities, equipment or fuel supply,
		acts of God, war, riot, civil disturbances, strike, labor disturbances, labor
		or material shortage, national emergency, restraint by court order or other
		Government Authority, interruption of synchronous operation, or other similar
		or dissimilar causes beyond the control of the Party affected, which causes
		such Party could not have avoided by ‘exercising Good Utility Practice:
		Nothing contained herein shall be construed to require a Party to settle any
		strike, lockout, work stoppage, or other industrial disturbance or dispute in
		which it may be involved or to take an appeal from any judicial, regulatory or
		administrative action.
	 

	 
		B. Transfer of Title and
		Indemnification
	 

	 
		Title and risk of loss related to the Power
		Supply Requirements shall transfer to the Buyer at the Delivery Points. Seller
		warrants that it will deliver the Power Supply Requirements to Buyer free and
		clear of all liens, security interests, claims and encumbrances or any interest
		therein or thereto by any person arising prior to the Delivery Points. Each
		Party shall indemnify, defend and hold harmless the other Party from and
		against any claims arising from or out of any event, circumstance, act or
		incident first occurring or existing during the period when control and title
		to the Power Supply Requirements is vested in the other Party.
	 

	 
		C. Confidentiality
	 

	 
		 
	 

	 
	 

	 

	 
		Neither Party shall disclose to third
		parties Confidential Information obtained from the other Party pursuant to this
		Agreement except in order to comply with the requirements of FERC, NERC,
		Electric Reliability Organization, applicable regional reliability councils or
		Regional Entity, Regional Transmission Organization, or Government -Authority.
		Each Party shall use reasonable efforts to prevent or limit the disclosure
		required to third parties under this section.
	 

	 
		D. Further Assurances
	 

	 
		Subject to the terms and conditions of this
		Agreement, each of the Parties will use reasonable efforts to take, or cause to
		be taken, all action, and to do, or cause to be done, all things necessary,
		proper or advisable under applicable laws and regulations to consummate and
		effectuate the transactions contemplated hereby.
	 

	 
		E. Assignment
	 

	 
		No assignment, pledge, or transfer of this
		Agreement shall be made by any Party without the prior written consent of the
		other Party, which consent shall not be unreasonably withheld. No prior written
		consent shall be required for (i) the assignment, pledge or . other transfer to
		another company or affiliate in the same holding company system as the
		assignor, pledgor or transferor, or (ii) the transfer incident to a merger or
		consolidation with, or transfer of all (or substantially all) of the assets of
		the transferor, to another person or business entity; provided, however, that
		such assignee, pledgee, transferee or acquirer of such assets or the person
		with which it merges or into which it consolidates assumes in writing all of
		the obligations of such Party hereunder and provided, further, that either
		Party may, without the consent of the other Party (and without relieving itself
		from liability hereunder), transfer, sell, pledge, encumber or assign such
		Party’s rights to the accounts, revenues or proceeds hereof in connection
		with any financing or other financial arrangements.
	 

	 
		F. Governing Law
	 

	 
		The interpretation and performance of this
		Agreement shall be according to and controlled by the laws of the Sctate of
		Ohio regardless of the laws that might otherwise govern under applicable
		principles of conflicts of laws.
	 

	 
		G. Counterparts
	 

	 
		This Agreement may be executed in two or
		more counterparts and each such counterpart shall constitute one and the same
		instrument.
	 

	 
		H. Waiver
	 

	 
		No waiver by a Party of any default by the
		other Party shall be construed as a waiver of any other default. Any waiver
		shall be effective only for the particular event for which it is issued and
		shall not be deemed a waiver with respect to any subsequent performance,
		default or matter.
	 

	 
		I. No Third Party Beneficiaries
	 

	 
		 
	 

	 
	 

	 

	 
		This Agreement shall not impart any rights
		enforceable by any third party other than a permitted successor or assignee
		bound to this Agreement.
	 

	 
		J. Severability
	 

	 
		Any provision of this Agreement declared or
		rendered unlawful by any applicable court of law or regulatory agency or deemed
		unlawful because of a statutory change will not otherwise affect the remaining
		lawful obligations that arise under this Agreement.
	 

	 
		K. Construction
	 

	 
		The term “including” when used in
		this Agreement shall be by way of example only and shall not be considered in
		any way to be a limitation. The headings used herein are for convenience and
		reference purposes only.
	 

	 
		IN WITNESS WHEREOF, the Parties have caused
		their duly authorized representatives to execute this Agreement on their behalf
		as of January 1, 2007.
	 

	 
		 
	 

	 
			
				
				   
				

			 	
				
				   
				

			 	
				
				   
				

			 	
				
				  FirstEnergy Solutions
				  Corp.
				

			 
	
				
				   
				

			 	
				
				   
				

			 	
				
				   
				

			 	
				
				   
				

			 
	
				
				

			 	
				
				   
				

			 	
				
				   
				

			 	
				
				  
 /s/ Guy Pipitone
				

			 
	
				
				   
				

			 	
				
				   
				

			 	
				
				   
				

			 	
				
				  President, FirstEnergy Solutions
				  Corp.
				

			 

 

	 
		 
	 

	 
			
				
				   
				

			 	
				
				   
				

			 	
				
				   
				

			 	
				
				  FirstEnergy Generation
				  Corp.
				

			 
	
				
				

			 	
				
				   
				

			 	
				
				   
				

			 	
				
				  
 /s/ Ali Jamshidi
				

			 
	
				
				   
				

			 	
				
				   
				

			 	
				
				   
				

			 	
				
				  President, FirstEnergy Generation
				  Corp.
				

			 

 

	 
		 
	 

	 
		 
	 

	 
	 

	 

	 
		EXHIBIT A
	 

	 
		 
	 

	 
		FIRSTENERGY GENERATION CORP.
	 

	 
		MONTHLY CHARGE FORMULA
	 

	 
		FirstEnergy Generation Corp.
	 

	 
		Monthly Revenue Requirement
		Formula
	 

	 
		Development of Investment Base (Note
		1)
	 

	 
		Month, XXXX
	 

	 
		 
	 

	 
			
				
				  Line
 No.
				

			 	
				
				  Description
				

			 	
				
				  Amount
				

			 	
				
				  Reference/Source
				

			 
	
				
				  1
				

			 	
				
				  Plant in Service
				

			 	
				
				   
				

			 	
				
				  FERC Acts. 101,106 (note
				  2)
				

			 
	
				
				  2
				

			 	
				
				  Accumulated Depreciation
				  &
 Amortization
				

			 	
				
				   
				

			 	
				
				  FERC Acts. 108,111 (note
				  2)
				

			 
	
				
				   
				

			 	
				
				   
				

			 	
				
				   
				

			 	
				
				   
				

			 
	
				
				  3
				

			 	
				
				  Net Utility Plant
				

			 	
				
				   
				

			 	
				
				  Line 1 plus Line 2
				

			 
	
				
				   
				

			 	
				
				   
				

			 	
				
				   
				

			 	
				
				   
				

			 
	
				
				  4
				

			 	
				
				  Fuel Stock
				

			 	
				
				   
				

			 	
				
				  FERC Act. 151
				

			 
	
				
				   
				

			 	
				
				   
				

			 	
				
				   
				

			 	
				
				   
				

			 
	
				
				  5
				

			 	
				
				  Materials and Supplies

				

			 	
				
				   
				

			 	
				
				  FERC Acts. 154, 163
				

			 
	
				
				   
				

			 	
				
				   
				

			 	
				
				   
				

			 	
				
				   
				

			 
	
				
				  6
				

			 	
				
				  Prepayments
				

			 	
				
				   
				

			 	
				
				  FERC Acts. 165
				

			 
	
				
				   
				

			 	
				
				   
				

			 	
				
				   
				

			 	
				
				   
				

			 
	
				
				  7
				

			 	
				
				  Working Cash
				

			 	
				
				   
				

			 	
				
				  1/8 times (O&M expense less
				  fuel)
				

			 
	
				
				   
				

			 	
				
				   
				

			 	
				
				   
				

			 	
				
				   
				

			 
	
				
				  8
				

			 	
				
				  Accumulated Deferred Income
				  Taxes
				

			 	
				
				   
				

			 	
				
				  FERC Acts 190, 281, 282,
				  283
				

			 
	
				
				   
				

			 	
				
				   
				

			 	
				
				   
				

			 	
				
				   
				

			 
	
				
				  9
				

			 	
				
				  Investment Base
				

			 	
				
				   
				

			 	
				
				  Sum of Lines 3-8
				

			 

 

	 
		Notes
	 

	 
			
				
				  1.
				

			 	
				
				  To be determined based on data as of
				  the end of the month immediately preceding the current service month.
				

			 

 

	 
			
				
				  2.
				

			 	
				
				  Includes amounts associated with
				  step-up facilities at the generating plants. Excludes Asset Retirement Costs
				  from Account 101- and the accumulated amortization associated with the Asset
				  Retirement Costs from Account 108.
				

			 

 

	 
		 
	 

	 
	 

	 

	 
		FirstEnergy Generation Corp.
	 

	 
		Monthly Revenue Requirement
		Formula
	 

	 
		Development of Monthly Revenue
		Requirement (Note 1)
	 

	 
		Calendar 2006 Estimate ($000)
	 

	 
		 
	 

	 
			
				
				  Line
 No.
				

			 	
				
				  Description
				

			 	
				
				  Amount
				

			 	
				
				  Reference/Source
				

			 
	
				
				  1
				

			 	
				
				  Monthly Revenue
				  Requirement
				

			 	
				
				   
				

			 	
				
				  (Note 2)
				

			 
	
				
				   
				

			 	
				
				   
				

			 	
				
				   
				

			 	
				
				   
				

			 
	
				
				  2
				

			 	
				
				  Operation & Maintenance
				  Expense
				

			 	
				
				   
				

			 	
				
				  FERC Acts. 500-514, 535-540,
				  541-547,
 555-557, 560-573 (Note
				  3), 920-931, 935
				

			 
	
				
				   
				

			 	
				
				   
				

			 	
				
				   
				

			 	
				
				   
				

			 
	
				
				  3
				

			 	
				
				  Depreciation Expense
				

			 	
				
				   
				

			 	
				
				  FERC Act. 403 (Note 3)

				

			 
	
				
				  4
				

			 	
				
				  Accretion Expense
				

			 	
				
				   
				

			 	
				
				  FERC Act. 411 Associated with
				  Accretion Expense
				

			 
	
				
				  5
				

			 	
				
				  Amortization Expense
				

			 	
				
				   
				

			 	
				
				  FERC Acts. 404, 407.3,
				  407.4
				

			 
	
				
				  6
				

			 	
				
				  Taxes other than Income
				  Taxes
				

			 	
				
				   
				

			 	
				
				  FERC Act. 408.1
				

			 
	
				
				  7
				

			 	
				
				  Current State Income
				  Tax
				

			 	
				
				   
				

			 	
				
				  Page 3, Line 18
				

			 
	
				
				  8
				

			 	
				
				  Current Federal Income
				  Tax
				

			 	
				
				   
				

			 	
				
				  Page 3, Line 25
				

			 
	
				
				  9
				

			 	
				
				  Provision for Deferred Income
				  Tax-
 State
				

			 	
				
				   
				

			 	
				
				  State portion of FERC Acts.
				  410.1, 411.1
 (Note 4)

				

			 
	
				
				  10
				

			 	
				
				  Provision for Deferred Income
				  Tax-
 Federal
				

			 	
				
				   
				

			 	
				
				  Federal portion of FERC Acts.
				  410.1,
 411.1 (Note 4)

				

			 
	
				
				  11
				

			 	
				
				  Investment Tax Credit –
				  Net
				

			 	
				
				   
				

			 	
				
				  FERC Act. 411.4
				

			 
	
				
				   
				

			 	
				
				   
				

			 	
				
				   
				

			 	
				
				   
				

			 
	
				
				  12
				

			 	
				
				  Utility Operating
				  Expenses
				

			 	
				
				   
				

			 	
				
				  Sum of Lines 2-11
				

			 
	
				
				   
				

			 	
				
				   
				

			 	
				
				   
				

			 	
				
				   
				

			 
	
				
				  13
				

			 	
				
				  Utility Operating
				  Income
				

			 	
				
				   
				

			 	
				
				  Line 1 minus Line 12
				

			 
	
				
				   
				

			 	
				
				   
				

			 	
				
				   
				

			 	
				
				   
				

			 
	
				
				  14
				

			 	
				
				  Verification:
				

			 	
				
				   
				

			 	
				
				   
				

			 
	
				
				  15
				

			 	
				
				  Investment Base
				

			 	
				
				   
				

			 	
				
				  Page 1, Line 9
				

			 
	
				
				  16
				

			 	
				
				  Rate of Return on Investment
				  Base
				

			 	
				
				   
				

			 	
				
				  12 times (Line 13/Line 15); Must
				  equal
 Line 17
				

			 
	
				
				  17
				

			 	
				
				  Cost of Capital
				

			 	
				
				   
				

			 	
				
				  Weighted Cost Rate from Page 4,
				  Line 3
				

			 

 

	 
		Notes
	 

	 
			
				
				  1.
				

			 	
				
				  All expenses are to be those for the
				  current service month.
				

			 

 

	 
			
				
				  2.
				

			 	
				
				  The Monthly Revenue Requirement is
				  the gross amount which when O&M expenses are subtracted results in an
				  Utility Operating Income (line 13) which when divided by the Investment Base
				  (Page 1, Line 9) produces a Rate of Return on Investment Base equal to the Cost
				  of Capital (determined in accordance with Page 4).
				

			 

 

	 
			
				
				  3.
				

			 	
				
				  Includes amounts associated with
				  step-up facilities at the generating plants.
				

			 

 

	 
			
				
				  4.
				

			 	
				
				  Restricted to those items for which
				  corresponding timing differences are included in the adjustments to Net Income
				  Before Income Tax (see Page 3, Line 7).
				

			 

 

	 
		 
	 

	 
	 

	 

	 
		FirstEnergy Generation Corp.
	 

	 
		Monthly Revenue Requirement
		Formula
	 

	 
		Development of Current Income Tax
		Expense
	 

	 
		Month, XXXX
	 

	 
		 
	 

	 
			
				
				  Line
 No.
				

			 	
				
				  Description
				

			 	
				
				  Amount
				

			 	
				
				  Reference/Source
				

			 
	
				
				  1
				

			 	
				
				  Monthly Revenue
				  Requirement
				

			 	
				
				   
				

			 	
				
				  Page 2, Line 1
				

			 
	
				
				   
				

			 	
				
				   
				

			 	
				
				   
				

			 	
				
				   
				

			 
	
				
				  2
				

			 	
				
				  Operation & Maintenance
				  Expense
				

			 	
				
				   
				

			 	
				
				  Page 2, Line 2
				

			 
	
				
				  3
				

			 	
				
				  Depreciation Expense
				

			 	
				
				   
				

			 	
				
				  Page 2, Line 3
				

			 
	
				
				  4
				

			 	
				
				  Accretion Expense
				

			 	
				
				   
				

			 	
				
				  Page 2, Line 4
				

			 
	
				
				  5
				

			 	
				
				  Amortization Expense
				

			 	
				
				   
				

			 	
				
				  Page 2, Line 5
				

			 
	
				
				  6
				

			 	
				
				  Taxes other than Income
				  Taxes
				

			 	
				
				   
				

			 	
				
				  Page 2, Line 6
				

			 
	
				
				  7
				

			 	
				
				  Net Income Before
				  Taxes
				

			 	
				
				   
				

			 	
				
				  Line 1 minus (Sum of Lines
				  2-6)
				

			 
	
				
				   
				

			 	
				
				   
				

			 	
				
				   
				

			 	
				
				   
				

			 
	
				
				  8
				

			 	
				
				  Adjustments to Net Income
				  Before
				

			 	
				
				   
				

			 	
				
				   
				

			 
	
				
				   
				

			 	
				
				  Income Tax:
				

			 	
				
				   
				

			 	
				
				   
				

			 
	
				
				  9
				

			 	
				
				  Interest
				  Synchronization
				

			 	
				
				   
				

			 	
				
				  [Investment Base (Page 1, Line 9)
				  times (-1) times
 Total Debt Rate
				  (Page 4, Line 1)] divided by 12
				

			 
	
				
				  10
				

			 	
				
				  Other Adjustments
				

			 	
				
				   
				

			 	
				
				  (Note 1)
				

			 
	
				
				  11
				

			 	
				
				  Total Adjustments
				

			 	
				
				   
				

			 	
				
				  Line 9 plus Line 10
				

			 
	
				
				  12
				

			 	
				
				  Taxable Income
				

			 	
				
				   
				

			 	
				
				  Line 7 plus Line 11
				

			 
	
				
				   
				

			 	
				
				   
				

			 	
				
				   
				

			 	
				
				   
				

			 
	
				
				   
				

			 	
				
				  Computation of State Income
				  Tax
				

			 	
				
				   
				

			 	
				
				   
				

			 
	
				
				  13
				

			 	
				
				  State Taxable Income before
				  Adjustments
				

			 	
				
				   
				

			 	
				
				  Line 12
				

			 
	
				
				  14
				

			 	
				
				  Net Adjustment to State Taxable
				  Income
				

			 	
				
				   
				

			 	
				
				  (Note 1)
				

			 
	
				
				  15
				

			 	
				
				  State Taxable Income
				

			 	
				
				   
				

			 	
				
				  Line 13 plus Line 14
				

			 
	
				
				   
				

			 	
				
				   
				

			 	
				
				   
				

			 	
				
				   
				

			 
	
				
				  16
				

			 	
				
				  State Income Tax before
				  Adjustments
				

			 	
				
				   
				

			 	
				
				  Line 15 times Ohio/Pennsylvania
				  State Tax Rate
 (Note
				  2)
				

			 
	
				
				  17
				

			 	
				
				  Adjustments to State
				  Tax
				

			 	
				
				   
				

			 	
				
				  (Note 1)
				

			 
	
				
				   
				

			 	
				
				   
				

			 	
				
				   
				

			 	
				
				   
				

			 
	
				
				  18
				

			 	
				
				  Current State Income
				  Tax
				

			 	
				
				   
				

			 	
				
				  Sum of Line 16 and 17
				

			 
	
				
				   
				

			 	
				
				   
				

			 	
				
				   
				

			 	
				
				   
				

			 
	
				
				   
				

			 	
				
				  Computation of Federal Income
				  Tax
				

			 	
				
				   
				

			 	
				
				   
				

			 
	
				
				  19
				

			 	
				
				  Federal Taxable Income
				  before
 Adjustments
				

			 	
				
				   
				

			 	
				
				  Line 12
				

			 
	
				
				   
				

			 	
				
				   
				

			 	
				
				   
				

			 	
				
				   
				

			 
	
				
				  20
				

			 	
				
				  Current State Income Tax
				  Deduction
				

			 	
				
				   
				

			 	
				
				  Line 18 (shown as
				  deduction)
				

			 
	
				
				  21
				

			 	
				
				  Other Adjustments to Federal
				  Taxable
 Income
				

			 	
				
				   
				

			 	
				
				  (Note 1)
				

			 
	
				
				   
				

			 	
				
				   
				

			 	
				
				   
				

			 	
				
				   
				

			 
	
				
				  22
				

			 	
				
				  Federal Taxable Income

				

			 	
				
				   
				

			 	
				
				  Sum of Line 19 –
				  21
				

			 
	
				
				   
				

			 	
				
				   
				

			 	
				
				   
				

			 	
				
				   
				

			 
	
				
				  23
				

			 	
				
				  Federal Income Tax before
				  Adjustments
				

			 	
				
				   
				

			 	
				
				  Line 22 times Federal Tax Rate
				  (Note 2)
				

			 
	
				
				   
				

			 	
				
				   
				

			 	
				
				   
				

			 	
				
				   
				

			 
	
				
				  24
				

			 	
				
				  Adjustments to Federal
				  Tax
				

			 	
				
				   
				

			 	
				
				  (Note 1)
				

			 
	
				
				   
				

			 	
				
				   
				

			 	
				
				   
				

			 	
				
				   
				

			 
	
				
				  25
				

			 	
				
				  Current Federal Income
				  Tax
				

			 	
				
				   
				

			 	
				
				  Sum of Lines 23 and 24

				

			 

 

	 
		 
	 

	 
	 

	 

	 
		Notes
	 

	 
			
				
				  1.
				

			 	
				
				  Items from monthly tax determination
				  that are appropriate for ratemaking purposes.
				

			 

 

	 
			
				
				  2.
				

			 	
				
				  Rate in effect at the end of the
				  service month.
				

			 

 

	 
		 
	 

	 
	 

	 

	 
		FirstEnergy Generation Corp.
	 

	 
		Monthly Revenue Requirement
		Formula
	 

	 
		Development of Cost of Capital (Note
		1)
	 

	 
		Month, XXXX
	 

	 
		 
	 

	 
			
				
				  Line
 No.
				

			 	
				
				  Capital Source
				

			 	
				
				  Capital Amount

				  (Note 2)
				

			 	
				
				  Capitalization

				  Ratio (Note 3)
				

			 	
				
				  Cost Rate
 (Notes 4,6)
				

			 	
				
				  Weighted Cost

				  Rate (Note 5)
				

			 
	
				
				  1
				

			 	
				
				  Long Term Debt

				  FERC Acts. 221-226,
 233
				

			 	
				
				   
				

			 	
				
				   
				

			 	
				
				   
				

			 	
				
				   
				

			 
	
				
				  2
				

			 	
				
				  Common Equity

				  FERC Acts. 201, 202,
 205, 207, 213-216
 (Excluding 216.1)
				

			 	
				
				   
				

			 	
				
				   
				

			 	
				
				   
				

			 	
				
				   
				

			 
	
				
				  3
				

			 	
				
				  Total
				

			 	
				
				   
				

			 	
				
				   
				

			 	
				
				   
				

			 	
				
				   
				

			 

 

	 
		Notes
	 

	 
			
				
				  1.
				

			 	
				
				  To be determined based on data as of
				  the end of the month immediately preceding the current service month.
				

			 

 

	 
			
				
				  2.
				

			 	
				
				  Long Term Debt shall include all
				  issues and reflect the principal amount.
				

			 

 

	 
			
				
				  3.
				

			 	
				
				  Applicable capital amount divided by
				  total capital amount.
				

			 

 

	 
			
				
				  4.
				

			 	
				
				  Average cost rate for all
				  outstanding issues including applicable amortization of debt discount, premium
				  and expense together with amortization of loss or gain on reacquired
				  debt.
				

			 

 

	 
			
				
				  5.
				

			 	
				
				  Capitalization ratio for the
				  applicable capital source multiplied by the corresponding cost rate:
				

			 

 

	 
			
				
				  6.
				

			 	
				
				  The Common Equity Cost Rate shall be
				  10.5%
				

			 

 

	 
		 
	 

	 
	 

	 

	 
		EXHIBIT B
	 

	 
		 
	 

	 
		DEFINITIONS
	 

	 
		In addition to terms defined elsewhere in
		this Agreement, the terms listed below are defined as follows:
	 

	 
		Affiliate means, with respect to any person, any other person
		(other than an individual) that, directly or indirectly, through one or more
		intermediaries, controls, or is controlled by, or is under common control with,
		such person. For purposes of the foregoing definition, control means the direct
		or indirect ownership of more than fifty percent (50%) of the outstanding
		capital stock or other equity interests having ordinary voting power or ability
		to direct the affairs of the affiliate.
	 

	 
		Ancillary Services means Reactive Supply and Voltage Control from
		Generation Resources, Regulation and Frequency Response Service, Operating
		Reserve – Spinning Reserve Service, and Operating Reserve –
		Supplemental Service and such additional Ancillary Services as defined in the
		Open Access Transmission Tariff of the Transmission Provider and to the extent
		available from the Genco Facilities.
	 

	 
		Business Day means any day on which Federal Reserve member banks in
		New York City are open for business.
	 

	 
		Capacity means the resource that produces electric Energy,
		measured in megawatts.
	 

	 
		Confidential Information means any confidential, proprietary, trade secret,
		critical energy infrastructure information, or commercially sensitive
		information relating to the present or planned business of a Party that is
		supplied under this Agreement, and is identified as confidential by the Party
		supplying the information.
	 

	 
		Delivery Point means where Capacity, Energy, and Ancillary Services
		are supplied by the Seller at the point of interconnection between the Genco
		Facilities and the transmission facilities of Transmission Owner.
	 

	 
		Electric Reliability
		Organization has the meaning given in
		Section 215(a)(2) of the Federal Power Act.
	 

	 
		Emission Allowances means all present and future authorizations to emit
		specified units of pollutants or hazardous substances, which units are
		established by the Government Authority with jurisdiction over the Genco
		Facilities under (i) an air pollution and emissions reduction program designed
		to mitigate global warming, interstate or intra-state transport of air
		pollutants; (ii) a program designed to mitigate impairment of surface waters,
		watersheds, or groundwater; or (iii) any pollution reduction program with a
		similar purpose. Emission Allowances include allowances, as described above,
		regardless as to whether the Governmental Authority establishing such Emission
		Allowances designates such allowances by a name other than
		“allowances.”
	 

	 
		 
	 

	 
	 

	 

	 
		Energy means electric energy delivered under this Agreement at
		three-phase, 60-hertz alternating current measured in megawatt hours.
	 

	 
		FERC means The Federal Energy Regulatory Commission or its
		regulatory successor.
	 

	 
		Force Majeure has the meaning given in Section VILA.
	 

	 
		Good Utility Practice means any of the practices, methods and acts engaged in
		or approved by a significant portion 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 includes compliance with the standards
		adopted by NERC, its applicable regional councils, an Electric Reliability
		Organization or Regional Entity as approved by the FERC. 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 and consistently adhered to by utilities
		in the region.
	 

	 
		Government Authority means any federal, state, local, municipal or other
		governmental entity, authority or agency, department, board, court, tribunal,
		regulatory commission, or other body, whether legislative, judicial or
		executive, together or individually, exercising or entitled to exercise any
		administrative, executive, judicial, policy, regulatory or taxing authority or
		power over Buyer or Seller.
	 

	 
		Interest Rate means the lesser of Prime Rate plus two percent and the
		maximum rate permitted by applicable law.
	 

	 
		NERC means The North American Electric Reliability Council
		or any superseding organization with responsibility for establishing
		reliability standards for the interstate grid.
	 

	 
		Power means Capacity and/or Energy.
	 

	 
		Prime Rate means for any date, the per annum rate of interest
		announced from time to time by Citibank, NA as its prime rate for commercial
		loans, effective for such date as established from time to time by such
		bank.
	 

	 
		Regional Entity has the meaning given in Section 215(a)(7) of the
		Federal Power Act.
	 

	 
		Regional Transmission
		Organization has the meaning given in
		Section 3(27) of the Federal Power Act.
	 

	 
		Renewable Energy
		Attributes means any credits, offsets,
		benefits, or tradable instrument created by law and related to generation of
		Power from the Genco Facilities.
	 

	 
		Taxes means all ad
		valorem, property, occupation, utility,
		gross receipts, sales, use, excise and other taxes, governmental charges,
		licenses, permits and assessments, other than taxes based on net income or net
		worth.
	 

	 
		 
	 

	 
	 

	 

	 
		Transmission Owner means the entity that owns facilities used for the
		transmission of Power from the Genco Facilities.
	 

	 
		Transmission Provider means the utility or utilities, including Regional
		Transmission Organizations, transmitting Power on behalf of Buyer from the
		Delivery Point(s) under this Agreement.
	 

	 
		Transmission Provider
		OATT means the Open Access Transmission
		Tariff, Open Access Transmission and Energy Markets Tariff, or any other tariff
		of general applicability on file at the FERC under which the Transmission
		Provider offers transmission service.
	 

	 
		 
	 

	 
	 

	 

	 
		EXHIBIT C
	 

	 
		NDC in kW
	 

	 
		Genco Facilities
	 

	 
		This list of Genco Facilities will be
		modified from time to time to reflect changes in ownership and/or output of
		generation facilities available to Solutions under this Agreement.
	 

	 
		 
	 

	 
			
				
				  FirstEnergy
				

			 
	
				
				  GENERATION
				  CAPABILITIES
				

			 
	
				
				   
				

			 
	
				
				   
				

			 
	
				
				  PLANT
				  NAME
				

			 	
				
				  UNIT #
				

			 	
				
				  YEAR IN-

				  SERVICE
				

			 	
				
				  NAMEPLATE

				  RATINGS (KW)
				

			 	
				
				  NET
				  DEMONSTRATED
 CAPABILITY
				  (KW)
				

			 
	
				
				   
				

			 	
				
				   
				

			 	
				
				   
				

			 	
				
				   
				

			 	
				
				   
				

			 
	
				
				  ASHTABULA
				

			 	
				
				  5
				

			 	
				
				  1958
				

			 	
				
				  256,000
				

			 	
				
				  244,000
				

			 
	
				
				  ASHTABULA

				  Total
				

			 	
				
				   
				

			 	
				
				   
				

			 	
				
				  256,000
				

			 	
				
				  244,000
				

			 
	
				
				   
				

			 	
				
				   
				

			 	
				
				   
				

			 	
				
				   
				

			 	
				
				   
				

			 
	
				
				  BAY SHORE
				

			 	
				
				  1
				

			 	
				
				  1955
				

			 	
				
				  140,625
				

			 	
				
				  136,000
				

			 
	
				
				  BAY SHORE
				

			 	
				
				  2
				

			 	
				
				  1959
				

			 	
				
				  140,625
				

			 	
				
				  138,000
				

			 
	
				
				  BAY SHORE
				

			 	
				
				  3
				

			 	
				
				  1963
				

			 	
				
				  140,625
				

			 	
				
				  142,000
				

			 
	
				
				  BAY SHORE
				

			 	
				
				  4
				

			 	
				
				  1968
				

			 	
				
				  217,600
				

			 	
				
				  215,000
				

			 
	
				
				  BAY SHORE
				

			 	
				
				  CT
				

			 	
				
				  1967
				

			 	
				
				  16,000
				

			 	
				
				  17,000
				

			 
	
				
				  BAY SHORE

				  Total
				

			 	
				
				   
				

			 	
				
				   
				

			 	
				
				  655,475
				

			 	
				
				  648,000
				

			 
	
				
				   
				

			 	
				
				   
				

			 	
				
				   
				

			 	
				
				   
				

			 	
				
				   
				

			 
	
				
				  R.E. BURGER
				

			 	
				
				  3
				

			 	
				
				  1950
				

			 	
				
				  103,500
				

			 	
				
				  94,000
				

			 
	
				
				  R.E. BURGER
				

			 	
				
				  4
				

			 	
				
				  1955
				

			 	
				
				  156,250
				

			 	
				
				  156,000
				

			 
	
				
				  R.E. BURGER
				

			 	
				
				  5
				

			 	
				
				  1955
				

			 	
				
				  156,250
				

			 	
				
				  156,000
				

			 
	
				
				  R.E. BURGER
				

			 	
				
				  EMD (3)
				

			 	
				
				  1972
				

			 	
				
				  7,500
				

			 	
				
				  7,000
				

			 
	
				
				  R.E. BURGER

				  Total
				

			 	
				
				   
				

			 	
				
				   
				

			 	
				
				  423,500
				

			 	
				
				  413,000
				

			 
	
				
				   
				

			 	
				
				   
				

			 	
				
				   
				

			 	
				
				   
				

			 	
				
				   
				

			 
	
				
				  EASTLAKE
				

			 	
				
				  1
				

			 	
				
				  1953
				

			 	
				
				  123,000
				

			 	
				
				  132,000
				

			 
	
				
				  EASTLAKE
				

			 	
				
				  2
				

			 	
				
				  1953
				

			 	
				
				  123,000
				

			 	
				
				  132,000
				

			 
	
				
				  EASTLAKE
				

			 	
				
				  3
				

			 	
				
				  1954
				

			 	
				
				  123,000
				

			 	
				
				  132,000
				

			 
	
				
				  EASTLAKE
				

			 	
				
				  4
				

			 	
				
				  1956
				

			 	
				
				  208,000
				

			 	
				
				  240,000
				

			 
	
				
				  EASTLAKE
				

			 	
				
				  5
				

			 	
				
				  1972
				

			 	
				
				  680,000
				

			 	
				
				  597,000
				

			 
	
				
				  EASTLAKE
				

			 	
				
				  CT
				

			 	
				
				  1973
				

			 	
				
				  32,000
				

			 	
				
				  29,000
				

			 
	
				
				  EASTLAKE

				  Total
				

			 	
				
				   
				

			 	
				
				   
				

			 	
				
				  1,289,000

				

			 	
				
				  1,262,000

				

			 
	
				
				   
				

			 	
				
				   
				

			 	
				
				   
				

			 	
				
				   
				

			 	
				
				   
				

			 
	
				
				  EDGEWATER
				

			 	
				
				  CT (2)
				

			 	
				
				  1973
				

			 	
				
				  57,600
				

			 	
				
				  48,000
				

			 
	
				
				  EDGEWATER
				  Total
				

			 	
				
				   
				

			 	
				
				   
				

			 	
				
				  57,600
				

			 	
				
				  48,000
				

			 
	
				
				   
				

			 	
				
				   
				

			 	
				
				   
				

			 	
				
				   
				

			 	
				
				   
				

			 
	
				
				  LAKESHORE
				

			 	
				
				  18
				

			 	
				
				  1962
				

			 	
				
				  256,000
				

			 	
				
				  245,000
				

			 
	
				
				  LAKESHORE
				

			 	
				
				  EMD (2)
				

			 	
				
				  1966
				

			 	
				
				  4,000
				

			 	
				
				  4,000
				

			 
	
				
				  LAKESHORE

				  Total
				

			 	
				
				   
				

			 	
				
				   
				

			 	
				
				  260,000
				

			 	
				
				  249,000
				

			 
	
				
				   
				

			 	
				
				   
				

			 	
				
				   
				

			 	
				
				   
				

			 	
				
				   
				

			 
	
				
				   
				

			 	
				
				   
				

			 	
				
				   
				

			 	
				
				   
				

			 	
				
				   
				

			 
	
				
				  MAD RIVER
				

			 	
				
				  CT (2)
				

			 	
				
				  1972
				

			 	
				
				  54,000
				

			 	
				
				  60,000
				

			 
	
				
				  MAD RIVER

				

			 	
				
				   
				

			 	
				
				   
				

			 	
				
				   
				

			 	
				
				   
				

			 

 

	 
		 
	 

	 
		 
	 

	 
	 

	 

	 
		 
	 

	 
			

				
				  Total
				

			 	
				
				   
				

			 	

				
				   
				

			 	

				
				  54,000
				

			 	

				
				  60,000
				

			 
	
				
				   
				

			 	
				
				   
				

			 	
				
				   
				

			 	
				
				   
				

			 	
				
				   
				

			 
	
				
				  MANSFIELD
				

			 	
				
				  1
				

			 	
				
				  1976
				

			 	
				
				  913,750
				

			 	
				
				  830,000
				

			 
	
				
				  MANSFIELD
				

			 	
				
				  2
				

			 	
				
				  1977
				

			 	
				
				  913,750
				

			 	
				
				  780,000
				

			 
	
				
				  MANSFIELD
				

			 	
				
				  3
				

			 	
				
				  1980
				

			 	
				
				  913,750
				

			 	
				
				  800,000
				

			 
	
				
				  MANSFIELD
				  Total
				

			 	
				
				   
				

			 	
				
				   
				

			 	
				
				  2,741,250

				

			 	
				
				  2,410,000

				

			 
	
				
				   
				

			 	
				
				   
				

			 	
				
				   
				

			 	
				
				   
				

			 	
				
				   
				

			 
	
				
				  RICHLAND
				

			 	
				
				  CT 1-3
				

			 	
				
				  1967
				

			 	
				
				  45,000
				

			 	
				
				  42,000
				

			 
	
				
				  RICHLAND
				

			 	
				
				  CT 4-6
				

			 	
				
				  2001
				

			 	
				
				  390,000
				

			 	
				
				  390,000
				

			 
	
				
				  RICHLAND

				  Total
				

			 	
				
				   
				

			 	
				
				   
				

			 	
				
				  435,000
				

			 	
				
				  432,000
				

			 
	
				
				   
				

			 	
				
				   
				

			 	
				
				   
				

			 	
				
				   
				

			 	
				
				   
				

			 
	
				
				  SAMMIS
				

			 	
				
				  1
				

			 	
				
				  1959
				

			 	
				
				  190,400
				

			 	
				
				  180,000
				

			 
	
				
				  SAMMIS
				

			 	
				
				  2
				

			 	
				
				  1960
				

			 	
				
				  190,400
				

			 	
				
				  180,000
				

			 
	
				
				  SAMMIS
				

			 	
				
				  3
				

			 	
				
				  1961
				

			 	
				
				  190,400
				

			 	
				
				  180,000
				

			 
	
				
				  SAMMIS
				

			 	
				
				  4
				

			 	
				
				  1962
				

			 	
				
				  190,400
				

			 	
				
				  180,000
				

			 
	
				
				  SAMMIS
				

			 	
				
				  5
				

			 	
				
				  1967
				

			 	
				
				  334,050
				

			 	
				
				  300,000
				

			 
	
				
				  SAMMIS
				

			 	
				
				  6
				

			 	
				
				  1969
				

			 	
				
				  680,000
				

			 	
				
				  600,000
				

			 
	
				
				  SAMMIS
				

			 	
				
				  7
				

			 	
				
				  1971
				

			 	
				
				  680,000
				

			 	
				
				  600,000
				

			 
	
				
				  SAMMIS
				

			 	
				
				  EMD (5)
				

			 	
				
				  1972
				

			 	
				
				  12,500
				

			 	
				
				  13,000
				

			 
	
				
				  SAMMIS

				  Total
				

			 	
				
				   
				

			 	
				
				   
				

			 	
				
				  2,468,150

				

			 	
				
				  2,233,000

				

			 
	
				
				   
				

			 	
				
				   
				

			 	
				
				   
				

			 	
				
				   
				

			 	
				
				   
				

			 
	
				
				  SENECA
				

			 	
				
				  1
				

			 	
				
				  1970
				

			 	
				
				  220,000
				

			 	
				
				  210,000
				

			 
	
				
				  SENECA
				

			 	
				
				  2
				

			 	
				
				  1970
				

			 	
				
				  220,000
				

			 	
				
				  195,000
				

			 
	
				
				  SENECA
				

			 	
				
				  3
				

			 	
				
				  1970
				

			 	
				
				  29,000
				

			 	
				
				  30,000
				

			 
	
				
				  SENECA
				  Total
				

			 	
				
				   
				

			 	
				
				   
				

			 	
				
				  469,000
				

			 	
				
				  435,000
				

			 
	
				
				   
				

			 	
				
				   
				

			 	
				
				   
				

			 	
				
				   
				

			 	
				
				   
				

			 
	
				
				  STRYKER
				

			 	
				
				  CT
				

			 	
				
				  1968
				

			 	
				
				  19,000
				

			 	
				
				  18,000
				

			 
	
				
				  STRYKER

				  Total
				

			 	
				
				   
				

			 	
				
				   
				

			 	
				
				  19,000
				

			 	
				
				  18,000
				

			 
	
				
				   
				

			 	
				
				   
				

			 	
				
				   
				

			 	
				
				   
				

			 	
				
				   
				

			 
	
				
				  SUMPTER
				

			 	
				
				  CT 1-4
				

			 	
				
				  2002
				

			 	
				
				  340,000
				

			 	
				
				  340,000
				

			 
	
				
				  SUMPTER

				  Total
				

			 	
				
				   
				

			 	
				
				   
				

			 	
				
				  340,000
				

			 	
				
				  340,000
				

			 
	
				
				   
				

			 	
				
				   
				

			 	
				
				   
				

			 	
				
				   
				

			 	
				
				   
				

			 
	
				
				  WEST LORAIN
				

			 	
				
				  CT 1A

				  & 1B
				

			 	
				
				  1973
				

			 	
				
				  130,600
				

			 	
				
				  120,000
				

			 
	
				
				  WEST LORAIN
				

			 	
				
				  CT 2-6
				

			 	
				
				  2001
				

			 	
				
				  425,000
				

			 	
				
				  425,000
				

			 
	
				
				  WEST LORAIN

				  Total
				

			 	
				
				   
				

			 	
				
				   
				

			 	
				
				  555,600
				

			 	
				
				  545,000
				

			 
	
				
				   
				

			 	
				
				   
				

			 	
				
				   
				

			 	
				
				   
				

			 	
				
				   
				

			 
	
				
				  OVEC
 

				  Total
				

			 	
				
				   
				

			 	
				
				   
				

			 	

				
				  
 
 10,023,575
				

			 	

				
				  466,000
 

				  9,803,000

Source: [{"source": "alea-institute/alea-institute/kl3m-data-edgar-agreements/train-00128-of-00352.parquet"}, [{"source": "alea-institute/alea-institute/kl3m-data-edgar-agreements/train-00128-of-00352.parquet"}]]