PRIOR PRINTER'S NO. 1477 PRINTER'S NO. 2262
No. 1134 Session of 2007
INTRODUCED BY TOMLINSON, M. WHITE, PILEGGI, RAFFERTY,
WASHINGTON, ERICKSON, KITCHEN, LOGAN AND GREENLEAF,
OCTOBER 19, 2007
SENATOR TOMLINSON, CONSUMER PROTECTION AND PROFESSIONAL
LICENSURE, AS AMENDED, JUNE 26, 2008
AN ACT
1 Amending Title 66 (Public Utilities) of the Pennsylvania
2 Consolidated Statutes, in restructuring of electric utility
3 industry, FURTHER PROVIDING FOR DEFINITIONS; providing for <--
4 rate change mitigation and for energy efficiency and demand- <--
5 response measures; and further providing for duties of
6 electric distribution companies.
7 The General Assembly of the Commonwealth of Pennsylvania
8 hereby enacts as follows:
9 Section 1. Title 66 of the Pennsylvania Consolidated <--
10 Statutes is amended by adding sections to read:
11 § 2806.1. Rate change mitigation.
12 (a) Prepayment or deferment.--Following the expiration of a
13 generation rate cap, if a default service provider's total
14 retail rate for a customer class rises by more than 12%
15 following the expiration of a generation rate cap, the following
16 shall apply:
17 (1) The default service provider shall offer all of its
18 residential and small business customers using 25kW or less
19 in maximum registered peak load the opportunity to prepay or
1 defer a portion of the increase by implementing a deferral or
2 phase-in of the rate increase for up to three years.
3 (2) Competitively neutral rate mitigation options shall
4 be included in the rate deferral or phase-in program of the
5 default service provider to begin with the expiration of a
6 generation rate gap approved by the commission.
7 (3) Default service providers may fully recover the
8 reasonable carrying costs associated with a rate increase
9 deferral program, including associated administrative costs
10 and pay any reasonable carrying cost on prepayment by
11 customers.
12 (b) Other mitigation strategies.--In addition to the
13 mitigation strategy under subsection (a), a default service
14 provider may propose other reasonable rate mitigation strategies
15 that would reflect the incurrence of reasonable costs.
16 § 2806.2. Energy efficiency and demand-response measures.
17 (a) Policy.--It is the policy of the Commonwealth that
18 electric distribution companies are required to use cost-
19 effective energy efficiency and demand-response measures to
20 reduce delivery load. Requiring investment in cost-effective
21 energy efficiency and demand-response measures will reduce
22 direct and indirect costs to consumers by decreasing
23 environmental impacts and by avoiding or delaying the need for
24 new generation, transmission and distribution infrastructure.
25 (b) Goals.--Electric distribution companies shall implement
26 cost-effective energy efficiency and conservation measures to
27 meet the following energy saving goals:
28 (1) By May 31, 2013, each electric distribution company
29 shall reduce its total annual deliveries to retail customers
30 by 2%. This load reduction shall be measured against the
20070S1134B2262 - 2 -
1 expected load forecasted by the commission for June 1, 2012,
2 through May 31, 2013. The commission shall determine and make
3 public the forecasts to be used for each electric
4 distribution company no later than May 31, 2008.
5 (2) By November 30, 2013, the commission shall evaluate
6 the costs and benefits of these efficiency and conservation
7 programs. If the benefits have been shown to exceed the
8 costs, consistent with the total resource cost test, the
9 commission shall set additional, incremental energy
10 efficiency and conservation goals for the period ending May
11 31, 2018.
12 (3) After May 31, 2018, the commission shall continue to
13 evaluate the costs and benefits of efficiency and
14 conservation measures and may adopt additional incremental
15 load reduction standards for electric distribution companies.
16 (c) Reduction in peak demand.--
17 (1) Electric distribution companies shall implement
18 cost-effective demand response measures to reduce peak demand
19 by at least 3% in the 100 hours of highest demand. This
20 reduction will be measured against the electric distribution
21 company's peak demand in the 100 hours of greatest demand for
22 June 1, 2007, through May 31, 2008. The reductions shall be
23 accomplished by May 31, 2012.
24 (2) By November 31, 2012, the commission shall compare
25 the total costs of these demand-response measures to the
26 total savings in energy and capacity costs to Pennsylvania
27 retail customers. If the benefits have been shown to exceed
28 the costs, consistent with the total resource cost test, the
29 commission shall order electric distribution companies to
30 seek additional incremental peak demand reductions for the
20070S1134B2262 - 3 -
1 100 hours of greatest demand or an alternative measure
2 adopted by the commission. The reductions shall be measured
3 from the electric distribution company's peak demand for the
4 period from June 1, 2011, through May 31, 2012. The mandated
5 reductions shall be accomplished no later than May 31, 2017.
6 (3) After May 31, 2017, the commission shall continue to
7 evaluate the costs and benefits of demand-response measures
8 and may adopt additional incremental peak reduction standards
9 for electric distribution companies.
10 (d) Oversight.--Electric distribution companies shall be
11 responsible for overseeing the design, development and filing of
12 energy efficiency and demand-response plans with the commission.
13 Electric distribution companies shall implement 100% of the
14 demand-response measures in the plans. Electric distribution
15 companies shall implement 100% of the energy efficiency measures
16 approved by the commission and may, as part of that
17 implementation, outsource various aspects of program development
18 and implementation. A minimum of 10% of the entire portfolio of
19 cost-effective energy efficiency measures shall be procured from
20 units of local government, municipal corporations, school
21 districts and community college districts. The commission shall
22 coordinate the implementation of these measures. The portfolio
23 of measures, administered by the utilities, shall be designed to
24 achieve the annual savings targets described in subsections (b)
25 and (c). The utility and the commission shall agree upon a
26 reasonable portfolio of measures and determine the measurable
27 corresponding percentage of the savings goals associated with
28 measures implemented by the utility.
29 (e) Plan.--No later than November 15, 2008, each electric
30 distribution company shall file an energy efficiency and demand-
20070S1134B2262 - 4 -
1 response plan with the commission to meet the energy efficiency
2 and demand-response standards. No later than December 1, 2008,
3 each electric distribution company shall file an energy
4 efficiency, conservation and demand-response program to meet the
5 goals identified in subsections (b) and (c). Subsequent plans
6 shall be filed pursuant to the commission's direction to obtain
7 the delivered and peak load reduction goals. Every five years
8 thereafter, each electric distribution company shall file an
9 energy efficiency and demand-response plan with the commission.
10 If a distribution company does not file such a plan, it shall
11 face a penalty of $100,000 per day until the plan is filed. Each
12 utility's plan shall set forth the utility's proposals to meet
13 the utility's portion of the energy efficiency standards
14 identified in subsection (b) and the demand-response standards
15 identified in subsection (c). The commission shall seek public
16 comment on the utility's plan and shall issue an order approving
17 or disapproving each plan at a set date after its submission. If
18 the commission disapproves a plan, the commission shall describe
19 in detail the reasons for the disapproval and describe a
20 procedure by which the utility may file a revised draft of the
21 plan to satisfactorily address the commission's concerns. If the
22 utility does not refile with the commission within 60 days, the
23 utility shall be subject to penalties at a rate of $100,000 per
24 day until the plan is filed. This process shall continue and
25 penalties shall accrue until the utility has successfully filed
26 a portfolio of energy efficiency and demand-response measures.
27 Penalties shall be deposited into the appropriate sustainable
28 energy fund. In submitting proposed energy efficiency and
29 demand-response plans and funding levels to meet the savings
30 goals adopted by this section, the utility shall:
20070S1134B2262 - 5 -
1 (1) Demonstrate that its proposed energy efficiency and
2 demand-response measures will achieve the requirements of
3 this chapter.
4 (2) Present specific proposals to implement new building
5 and appliance standards that have been placed into effect.
6 (3) Present estimates of the total amount paid for
7 electric service expressed on a per kilowatt hour basis
8 associated with the proposed portfolio of measures designed
9 to meet the requirements of this chapter.
10 (4) Coordinate with the commission to present a
11 portfolio of energy efficiency measures targeted to
12 households at or below 150% of the poverty level at a level
13 proportionate to those households' share of total annual
14 utility revenues in this Commonwealth.
15 (5) Demonstrate that its overall portfolio of energy
16 efficiency and demand-response measures, not including
17 programs covered by paragraph (4), are cost effective using
18 the total resource cost test and represent a diverse cross
19 section of opportunities for customers of all rate classes to
20 participate in the programs.
21 (6) Include a proposed cost-recovery tariff mechanism to
22 fund the proposed energy efficiency and demand-response
23 measures and to ensure the recovery of the prudently and
24 reasonably incurred costs of commission-approved programs.
25 (7) Provide for an annual independent evaluation of the
26 performance of the cost-effectiveness of the utility's
27 portfolio of measures, as well as a full review of the five-
28 year results of the broader net program impacts and, to the
29 extent practicable, for adjustment of the measures on a
30 going-forward basis as a result of the evaluations. The
20070S1134B2262 - 6 -
1 resources dedicated to evaluation shall not exceed 3% of
2 portfolio resources in any given year.
3 (f) Allocation limit.--No more than 3% of energy efficiency
4 and demand-response program revenue may be allocated for
5 demonstration of breakthrough equipment and devices.
6 (g) Failure to meet standard.--If an electric distribution
7 company fails to meet the efficiency standards specified in
8 subsections (b) and (c), it shall be assessed a civil penalty in
9 an amount up to $5,000,000 in accordance with this subsection.
10 In addition, the responsibility for implementing the energy
11 efficiency measures of the utility making the payment shall be
12 transferred to the commission if, after five years, or in any
13 subsequent five-year period, the utility fails to meet the
14 efficiency standard. The commission shall implement a
15 competitive procurement program to procure resources necessary
16 to meet the standards in this chapter.
17 (h) Definitions.--As used in this section the following
18 words and phrases shall have the meanings given to them in this
19 subsection:
20 "Amount per kilowatt hour." The total amount paid for
21 electric service expressed on a per kilowatt hour basis.
22 "Cost-effective." Measures which satisfy the total resource
23 cost test.
24 "Total amount paid for electric service." The term includes,
25 without limitation, estimated amounts paid for generation,
26 transmission, distribution, surcharges and add-on taxes.
27 Section 2. Section 2807(e) of Title 66, amended July 17,
28 2007 (P.L.120, No.36), is amended to read:
29 § 2807. Duties of electric distribution companies.
30 * * *
20070S1134B2262 - 7 -
1 (e) Obligation to serve.--[An electric distribution
2 company's obligation to provide] The obligation of a default
3 service provider to furnish electric service following
4 implementation of restructuring and the choice of alternative
5 generation by a customer is revised as follows:
6 (1) While an electric distribution company collects
7 either a competitive transition charge or an intangible
8 transition charge or until 100% of its customers have choice,
9 whichever is longer, the electric distribution company shall
10 continue to have the full obligation to serve, including the
11 connection of customers, the delivery of electric energy and
12 the production or acquisition of electric energy for
13 customers.
14 [(2) At the end of the transition period, the commission
15 shall promulgate regulations to define the electric
16 distribution company's obligation to connect and deliver and
17 acquire electricity under paragraph (3) that will exist at
18 the end of the phase-in period.
19 (3) If a customer contracts for electric energy and it
20 is not delivered or if a customer does not choose an
21 alternative electric generation supplier, the electric
22 distribution company or commission-approved alternative
23 supplier shall acquire electric energy at prevailing market
24 prices to serve that customer and shall recover fully all
25 reasonable costs.]
26 (3.1) From and after the expiration of an electric
27 distribution company's obligation to supply electric energy
28 and capacity to retail customers at capped rates, if a
29 customer contracts for electric energy and capacity and the
30 chosen electric generation supplier does not supply the
20070S1134B2262 - 8 -
1 service or if a customer does not choose an alternative
2 electric generation supplier, the default service provider
3 shall provide electric generation supply service to that
4 customer pursuant to a commission-approved competitive
5 procurement plan. The electric power acquired to provide
6 electric generation service under this paragraph shall be
7 procured through competitive procurement processes that may
8 include one or more of the following:
9 (i) Auctions.
10 (ii) Requests for proposal.
11 (iii) Bilateral contracts negotiated between the
12 electric distribution company or commission-approved
13 alternative supplier and a wholesale electric supplier,
14 except that the bilateral contracts shall be entered into
15 at the sole discretion of the electric distribution
16 company or commission-approved alternative supplier and
17 the commission shall have no authority to require the
18 contracts and shall be at prices no greater than
19 reasonable forward market prices.
20 (iv) Any other electric energy approved by the
21 commission through regulation.
22 (3.2) The commission shall not modify contracts or
23 disallow costs associated with contracts entered into
24 pursuant to an approved competitive procurement process.
25 Prices obtained through the competitive procurement processes
26 shall be deemed to be prevailing market prices. The resources
27 procured pursuant to this paragraph may reflect a mix of
28 long-term, short-term or spot market purchases. The
29 commission may disallow cost recovery if there has been
30 fraud, collusion, market manipulation or similar activities
20070S1134B2262 - 9 -
1 with regard to these contracts.
2 (4) If a customer that chooses an alternative supplier
3 and subsequently desires to return to the local distribution
4 company for generation service, the local distribution
5 company shall treat that customer exactly as it would any new
6 applicant for energy service.
7 (5) (i) Notwithstanding paragraph (3), the electric
8 distribution company or commission-approved alternative
9 supplier may, in its sole discretion, offer large
10 customers with a peak demand of 15 megawatts or greater
11 at one meter at a location in its service territory any
12 negotiated rate for service at all of the customers'
13 locations within the service territory for any duration
14 agreed upon by the electric distribution company or
15 commission-approved alternative supplier and the large
16 customer. The commission shall permit, but shall not
17 require, an electric distribution company or commission-
18 approved alternative supplier to provide service to large
19 customers under this paragraph. Contract rates entered
20 into under this paragraph shall be subject to review by
21 the commission in order to ensure that all costs related
22 to the rates are borne by the parties to the contract and
23 that no costs related to the rates are borne by other
24 customers or customer classes. If no costs related to the
25 rates are borne by other customers or customer classes,
26 the commission shall approve the contract within 90 days
27 of its filing, or it shall be deemed approved by
28 operation of law upon expiration of the 90 days.
29 Information submitted under this paragraph shall be
30 subject to the commission's procedures for the filing of
20070S1134B2262 - 10 -
1 confidential and proprietary information.
2 (ii) For purposes of providing service under this
3 paragraph to customers with a peak demand of 20 megawatts
4 or greater at one meter at a location within that
5 distribution company's service territory, an electric
6 distribution company that has completed its restructuring
7 transition period as of the effective date of this
8 paragraph may, in its sole discretion, acquire an
9 interest in a generation facility or construct a
10 generation facility specifically to meet the energy
11 requirements of the customers, including the electric
12 requirements of the customers' other billing locations
13 within its service territory. The electric distribution
14 company must commence construction of the generation
15 facility or contract to acquire the generation interest
16 within three years after the effective date of this
17 paragraph, except that the electric distribution company
18 may add to the generation facilities it commenced
19 construction or contracted to acquire after this three-
20 year period to serve additional load of customers for
21 whom it commenced construction or contracted to acquire
22 generation within three years. Nothing in this paragraph
23 requires or authorizes the commission to require an
24 electric distribution company to commence construction or
25 acquire an interest in a generation facility. The
26 electric distribution company's interest in the
27 generation facility it built or contracted to acquire
28 shall be no larger than necessary to meet peak demand of
29 customers served under this subparagraph. During times
30 when the customer's demand is less than the electric
20070S1134B2262 - 11 -
1 distribution company's generation interest, the electric
2 distribution company may sell excess power on the
3 wholesale market. At no time shall the costs associated
4 with the generating facility interests be included in
5 rate base or otherwise reflected in rates. The generation
6 facility interests shall not be commission-regulated
7 assets.
8 Section 3. This act shall take effect in 60 days.
9 SECTION 1. SECTION 2803 OF TITLE 66 OF THE PENNSYLVANIA <--
10 CONSOLIDATED STATUTES IS AMENDED BY ADDING DEFINITIONS TO READ:
11 § 2803. DEFINITIONS.
12 THE FOLLOWING WORDS AND PHRASES WHEN USED IN THIS CHAPTER
13 SHALL HAVE THE MEANINGS GIVEN TO THEM IN THIS SECTION UNLESS THE
14 CONTEXT CLEARLY INDICATES OTHERWISE:
15 * * *
16 "BILATERAL CONTRACT." AN AGREEMENT, AS APPROVED BY THE
17 PENNSYLVANIA PUBLIC UTILITY COMMISSION, REACHED BY TWO PARTIES,
18 EACH ACTING IN ITS OWN INDEPENDENT SELF-INTEREST, AS A RESULT OF
19 NEGOTIATIONS FREE OF UNDUE INFLUENCE, DURESS OR FAVORITISM, IN
20 WHICH THE ELECTRIC ENERGY SUPPLIER AGREES TO SELL AND THE
21 ELECTRIC DISTRIBUTION COMPANY AGREES TO BUY A SPECIFIED QUANTITY
22 OF ELECTRIC ENERGY AT A PRICE FOR A SPECIFIED PERIOD OF TIME
23 UNDER TERMS AGREED TO BY BOTH PARTIES, AND WHICH FOLLOWS A
24 STANDARD INDUSTRY TEMPLATE WIDELY ACCEPTED IN THE INDUSTRY OR
25 VARIATIONS THERETO ACCEPTED BY THE PARTIES AND APPROVED BY THE
26 COMMISSION. STANDARD INDUSTRY TEMPLATES INCLUDE THE EEI MASTER
27 AGREEMENT FOR PHYSICAL ENERGY PURCHASES AND SALES AND THE ISDA
28 MASTER AGREEMENT FOR FINANCIAL ENERGY PURCHASES AND SALES.
29 * * *
30 "DEFAULT SERVICE PROVIDER." AN ELECTRIC DISTRIBUTION COMPANY
20070S1134B2262 - 12 -
1 WITHIN ITS CERTIFICATED SERVICE TERRITORY OR A PENNSYLVANIA
2 PUBLIC UTILITY COMMISSION-APPROVED ALTERNATIVE SUPPLIER
3 PROVIDING GENERATION SERVICE TO RETAIL ELECTRIC CUSTOMERS WHO:
4 (1) CONTRACT FOR ELECTRIC POWER, INCLUDING, BUT NOT
5 LIMITED TO, ENERGY AND CAPACITY, AND THE CHOSEN ELECTRIC
6 GENERATION SUPPLIER DOES NOT SUPPLY THE SERVICE; OR
7 (2) DO NOT CHOOSE AN ALTERNATIVE ELECTRIC GENERATION
8 SUPPLIER.
9 * * *
10 SECTION 2. TITLE 66 IS AMENDED BY ADDING A SECTION TO READ:
11 § 2806.1. RATE CHANGE MITIGATION.
12 (A) DEFERRAL PROGRAM.--AN ELECTRIC DISTRIBUTION COMPANY
13 WHOSE TOTAL RETAIL RATE INCLUDING GENERATION, TRANSMISSION AND
14 DISTRIBUTION SERVICE COMPONENTS AND ANY APPLICABLE SURCHARGE FOR
15 A CUSTOMER CLASS IS ANTICIPATED TO RISE BY MORE THAN 12% UPON
16 THE EXPIRATION OF A GENERATION RATE CAP ESTABLISHED IN AN
17 ELECTRIC UTILITY RESTRUCTURING PROCEEDING SPECIFIED IN SECTION
18 2804(4) (RELATING TO STANDARDS FOR RESTRUCTURING OF ELECTRIC
19 INDUSTRY) OR A RESTRUCTURING PLAN SHALL SUBMIT A RATE MITIGATION
20 PLAN TO THE COMMISSION FOR APPROVAL NO LATER THAN ONE YEAR PRIOR
21 TO THE DATE OF THE EXPIRATION OF THE GENERATION RATE CAP. THE
22 RATE MITIGATION PLAN SHALL PROVIDE THE FOLLOWING:
23 (1) A RATE MITIGATION PHASE-IN PROGRAM, WHICH SHALL BE
24 AUTHORIZED FOR RESIDENTIAL OR SMALL BUSINESS CUSTOMERS, USING
25 25KW OR LESS IN MAXIMUM REGISTERED PEAK LOAD. THE RATE
26 MITIGATION PROGRAM SHALL LIMIT THE ANTICIPATED TOTAL RETAIL
27 RATE INCREASE FOR THE INITIAL DEFAULT SERVICE GENERATION RATE
28 INCREASE FOR A PERIOD OF UP TO FIVE YEARS IN ACCORDANCE WITH
29 THE FOLLOWING:
30 (I) THE PLAN SHALL PROVIDE FOR RESIDENTIAL AND SMALL
20070S1134B2262 - 13 -
1 BUSINESS CUSTOMERS USING 25KW OR LESS TO BE PERMITTED TO
2 MAKE PAYMENTS IN ACCORDANCE WITH THE FOLLOWING SCHEDULE:
3 (A) YEAR ONE FOLLOWING THE EXPIRATION OF THE
4 GENERATION RATE CAPS - NO MORE THAN A 9% INCREASE
5 OVER THE RATE ON THE EFFECTIVE DATE OF THIS SECTION
6 OR AS CERTIFIED BY THE COMMISSION.
7 (B) YEAR TWO FOLLOWING THE EXPIRATION OF THE
8 GENERATION RATE CAPS - NO MORE THAN AN 18% INCREASE
9 OVER THE RATE ON THE EFFECTIVE DATE OF THIS SECTION
10 OR AS CERTIFIED BY THE COMMISSION.
11 (C) YEAR THREE FOLLOWING THE EXPIRATION OF THE
12 GENERATION RATE CAPS - NO MORE THAN A 27% INCREASE
13 OVER THE RATE ON THE EFFECTIVE DATE OF THIS SECTION
14 OR AS CERTIFIED BY THE COMMISSION.
15 (D) YEAR FOUR FOLLOWING THE EXPIRATION OF THE
16 GENERATION RATE CAPS - NO MORE THAN A 36% INCREASE
17 OVER THE RATE ON THE EFFECTIVE DATE OF THIS SECTION
18 OR AS CERTIFIED BY THE COMMISSION.
19 (E) YEAR FIVE FOLLOWING THE EXPIRATION OF THE
20 GENERATION RATE CAPS - NO MORE THAN A 45% INCREASE
21 OVER THE RATE ON THE EFFECTIVE DATE OF THIS SECTION
22 OR AS CERTIFIED BY THE COMMISSION.
23 (II) A CUSTOMER MAY ELECT, BUT SHALL NOT BE
24 REQUIRED, TO PARTICIPATE IN THE RATE MITIGATION PHASE-IN
25 PROGRAM UNDER THIS PARAGRAPH. THE ELECTRIC DISTRIBUTION
26 COMPANY SHALL PROVIDE NOTICE OF THE ABILITY TO ELECT TO
27 PARTICIPATE IN THE RATE MITIGATION PROGRAM IN AT LEAST
28 FOUR BILLING STATEMENTS PRIOR TO THE EXPIRATION OF THE
29 GENERATION RATE CAP. NOTICE SHALL ALSO BE POSTED ON THE
30 ELECTRIC DISTRIBUTION COMPANY'S INTERNET WEBSITE. THE
20070S1134B2262 - 14 -
1 NOTICE SHALL INCLUDE:
2 (A) A FORM TO ELECT PARTICIPATION IN THE
3 PROGRAM.
4 (B) A TOLL-FREE TELEPHONE NUMBER TO ALLOW A
5 CUSTOMER TO ELECT PARTICIPATION IN THE PROGRAM BY
6 TELEPHONE OR TO RECEIVE ADDITIONAL INFORMATION.
7 (III) IN ORDER TO PARTICIPATE IN THE RATE MITIGATION
8 PHASE-IN PROGRAM, THE CUSTOMER SHALL FILE A WRITTEN OR
9 ELECTRONIC ELECTION TO PARTICIPATE.
10 (2) A COMPETITIVELY NEUTRAL RATE MITIGATION OPTION
11 APPROVED BY THE COMMISSION BEFORE BEING IMPLEMENTED. A
12 CUSTOMER TAKING GENERATION SERVICE FROM EITHER THE DEFAULT
13 SERVICE PROVIDER OR AN ALTERNATIVE ELECTRIC GENERATION
14 SUPPLIER MAY SELECT THE OPTION.
15 (3) IN ADDITION TO THE MITIGATION STRATEGY UNDER THIS
16 SUBSECTION, AN ELECTRIC DISTRIBUTION COMPANY MAY PROPOSE
17 OTHER REASONABLE RATE MITIGATION STRATEGIES.
18 (B) COMMISSION DUTIES.--THE COMMISSION SHALL REVIEW THE PLAN
19 AND CERTIFY THE RATE AS OF THE EFFECTIVE DATE OF THIS SECTION AS
20 IT PERTAINS TO RESIDENTIAL AND SMALL BUSINESS CUSTOMERS USING
21 25KW OR LESS IN MAXIMUM REGISTERED PEAK LOAD PRIOR TO THE START
22 DATE OF THE PROGRAM.
23 SECTION 3. SECTION 2807(E) OF TITLE 66 IS AMENDED TO READ:
24 § 2807. DUTIES OF ELECTRIC DISTRIBUTION COMPANIES.
25 * * *
26 (E) OBLIGATION TO SERVE.--AN ELECTRIC DISTRIBUTION COMPANY'S
27 OBLIGATION TO PROVIDE ELECTRIC GENERATION SUPPLY SERVICE
28 FOLLOWING [IMPLEMENTATION OF RESTRUCTURING AND THE CHOICE OF
29 ALTERNATIVE GENERATION BY A CUSTOMER] THE EXPIRATION OF A
30 GENERATION RATE CAP SPECIFIED UNDER SECTION 2804(4) (RELATING TO
20070S1134B2262 - 15 -
1 STANDARDS FOR RESTRUCTURING OF ELECTRIC INDUSTRY) OR A
2 RESTRUCTURING PLAN UNDER SECTION 2806(F) IS REVISED AS FOLLOWS:
3 (1) WHILE AN ELECTRIC DISTRIBUTION COMPANY COLLECTS
4 EITHER A COMPETITIVE TRANSITION CHARGE OR AN INTANGIBLE
5 TRANSITION CHARGE OR UNTIL 100% OF ITS CUSTOMERS HAVE CHOICE,
6 WHICHEVER IS LONGER, THE ELECTRIC DISTRIBUTION COMPANY SHALL
7 CONTINUE TO HAVE THE FULL OBLIGATION TO SERVE, INCLUDING THE
8 CONNECTION OF CUSTOMERS, THE DELIVERY OF ELECTRIC ENERGY AND
9 THE PRODUCTION OR ACQUISITION OF ELECTRIC ENERGY FOR
10 CUSTOMERS.
11 [(2) AT THE END OF THE TRANSITION PERIOD, THE COMMISSION
12 SHALL PROMULGATE REGULATIONS TO DEFINE THE ELECTRIC
13 DISTRIBUTION COMPANY'S OBLIGATION TO CONNECT AND DELIVER AND
14 ACQUIRE ELECTRICITY UNDER PARAGRAPH (3) THAT WILL EXIST AT
15 THE END OF THE PHASE-IN PERIOD.
16 (3) IF A CUSTOMER CONTRACTS FOR ELECTRIC ENERGY AND IT
17 IS NOT DELIVERED OR IF A CUSTOMER DOES NOT CHOOSE AN
18 ALTERNATIVE ELECTRIC GENERATION SUPPLIER, THE ELECTRIC
19 DISTRIBUTION COMPANY OR COMMISSION-APPROVED ALTERNATIVE
20 SUPPLIER SHALL ACQUIRE ELECTRIC ENERGY AT PREVAILING MARKET
21 PRICES TO SERVE THAT CUSTOMER AND SHALL RECOVER FULLY ALL
22 REASONABLE COSTS.]
23 (3.1) FOLLOWING THE EXPIRATION OF AN ELECTRIC
24 DISTRIBUTION COMPANY'S OBLIGATION TO PROVIDE ELECTRIC
25 GENERATION SUPPLY SERVICE TO RETAIL CUSTOMERS AT CAPPED
26 RATES, IF A CUSTOMER CONTRACTS FOR ELECTRIC GENERATION SUPPLY
27 SERVICE AND THE CHOSEN ELECTRIC GENERATION SUPPLIER DOES NOT
28 PROVIDE THE SERVICE OR IF A CUSTOMER DOES NOT CHOOSE AN
29 ALTERNATIVE ELECTRIC GENERATION SUPPLIER, THE DEFAULT SERVICE
30 PROVIDER SHALL PROVIDE ELECTRIC GENERATION SUPPLY SERVICE TO
20070S1134B2262 - 16 -
1 THAT CUSTOMER PURSUANT TO A COMMISSION-APPROVED COMPETITIVE
2 PROCUREMENT PLAN. THE ELECTRIC POWER ACQUIRED SHALL BE
3 PROCURED THROUGH COMPETITIVE PROCUREMENT PROCESSES AND SHALL
4 INCLUDE A PRUDENT MIX OF THE FOLLOWING:
5 (I) AUCTIONS.
6 (II) REQUESTS FOR PROPOSAL.
7 (III) SPOT MARKET PURCHASES.
8 (IV) LONG-TERM PURCHASE CONTRACTS OF NOT LESS THAN
9 THREE AND NOT MORE THAN 20 YEARS, UNLESS THE COMMISSION
10 DETERMINES THAT A LONGER TERM IS NECESSARY FOR
11 RELIABILITY IN THE ACQUISITION OF GENERATION AND THAT IT
12 IS IN THE BEST INTEREST OF THE CONSUMER TO EXTEND THE
13 TERM OF THE CONTRACT BEYOND 20 YEARS.
14 (V) BILATERAL CONTRACTS WHICH SHALL BE AT PRICES
15 WHICH ARE:
16 (A) NO GREATER THAN THE COST OF OBTAINING
17 GENERATION IN THE WHOLESALE MARKET, AS DETERMINED BY
18 THE COMMISSION; OR
19 (B) CONSISTENT WITH A COMMISSION-APPROVED
20 COMPETITIVE PROCUREMENT PROCESS. ANY AGREEMENT
21 BETWEEN AFFILIATED PARTIES SHALL BE SUBJECT TO REVIEW
22 AND APPROVAL OF THE PENNSYLVANIA PUBLIC UTILITY
23 COMMISSION UNDER CHAPTER 21 (RELATING TO RELATIONS
24 WITH AFFILIATED INTERESTS). IN NO CASE SHALL THE COST
25 OF OBTAINING GENERATION FROM ANY AFFILIATED INTEREST
26 BE GREATER THAN THE COST OF OBTAINING GENERATION
27 UNDER COMPARABLE TERMS IN THE WHOLESALE MARKET AT THE
28 TIME OF PURCHASE.
29 (3.2) THE PRUDENT MIX OF RESOURCES ACQUIRED PURSUANT TO
30 PARAGRAPH (3.1) SHALL BE DESIGNED TO ENSURE:
20070S1134B2262 - 17 -
1 (I) ADEQUATE AND RELIABLE SERVICE.
2 (II) THE LEAST COST TO CUSTOMERS OVER TIME.
3 (III) COMPLIANCE WITH THE REQUIREMENTS OF PARAGRAPH
4 (3.1).
5 (3.3) THE DEFAULT SERVICE PROVIDER SHALL FILE A PLAN FOR
6 COMPETITIVE PROCUREMENT WITH THE COMMISSION AND OBTAIN
7 COMMISSION APPROVAL OF THE PLAN BEFORE THE COMPETITIVE
8 PROCESS IS IMPLEMENTED. THE COMMISSION SHALL HOLD HEARINGS AS
9 NECESSARY ON THE PROPOSED PLAN. IF THE COMMISSION FAILS TO
10 ISSUE A FINAL ORDER ON THE PLAN WITHIN NINE MONTHS OF THE
11 DATE THAT THE PLAN IS FILED, THE PLAN SHALL BE DEEMED TO BE
12 APPROVED AND THE DEFAULT SERVICE PROVIDER MAY IMPLEMENT THE
13 PLAN AS FILED. COSTS INCURRED THROUGH THE COMPETITIVE
14 PROCUREMENT PROCESSES SHALL BE DEEMED TO BE THE LEAST COST ON
15 A LONG-TERM BASIS.
16 (3.4) NOTWITHSTANDING SECTIONS 508 (RELATING TO POWER OF
17 COMMISSION TO VARY, REFORM AND REVISE CONTRACTS) AND 2102
18 (RELATING TO APPROVAL OF CONTRACTS WITH AFFILIATED
19 INTERESTS), THE COMMISSION SHALL NOT MODIFY CONTRACTS OR
20 DISALLOW COSTS ASSOCIATED WITH AN APPROVED PROCUREMENT
21 PROCESS WHEN IT HAS REVIEWED AND APPROVED THE RESULTS OF THE
22 PROCUREMENT, UNLESS OTHERWISE SPECIFIED UNDER THIS TITLE.
23 (3.5) IN DETERMINING IF THE DEFAULT ELECTRIC SERVICE
24 PROVIDER HAS OBTAINED GENERATION SUPPLY AT THE LEAST COST,
25 THE COMMISSION SHALL CONSIDER THE UTILITY'S OBLIGATION TO
26 PROVIDE ADEQUATE AND RELIABLE SERVICE TO CUSTOMERS, AND SHALL
27 MAKE SPECIFIC FINDINGS WHICH SHALL INCLUDE THE FOLLOWING:
28 (I) THE UTILITY HAS TAKEN ALL PRUDENT STEPS
29 NECESSARY TO NEGOTIATE FAVORABLE GENERATION SUPPLY
30 CONTRACTS AND TO RELIEVE THE UTILITY FROM TERMS IN
20070S1134B2262 - 18 -
1 EXISTING CONTRACTS WITH ITS GENERATION SUPPLIERS WHICH
2 ARE OR MAY BE ADVERSE TO THE INTERESTS OF THE UTILITY
3 CUSTOMERS.
4 (II) THE UTILITY HAS TAKEN ALL PRUDENT STEPS
5 NECESSARY TO OBTAIN LEAST COST GENERATION SUPPLY
6 CONTRACTS ON A LONG-TERM, SHORT-TERM AND SPOT MARKET
7 BASIS.
8 (III) NEITHER THE UTILITY NOR ITS AFFILIATED
9 INTEREST HAS WITHHELD FROM THE MARKET ANY GENERATION
10 SUPPLY WHICH SHOULD HAVE BEEN UTILIZED AS PART OF A LEAST
11 COST PROCUREMENT POLICY. THE GENERATION RATES PROCURED BY
12 A COMPETITIVE PROCUREMENT PROCESS SHALL NOT ALLOW THE
13 CROSS SUBSIDIZATION OF ONE CUSTOMER CLASS BY ANOTHER. THE
14 COMMISSION MAY DISALLOW COST RECOVERY IF THERE IS REASON
15 TO BELIEVE THAT FRAUD, COLLUSION OR MARKET MANIPULATION
16 WITH REGARD TO THESE CONTRACTS HAS OCCURRED OR FOR
17 FAILURE TO IMPLEMENT THE COMPETITIVE PROCUREMENT PLAN
18 APPROVED BY THE COMMISSION.
19 (3.6) NOTWITHSTANDING ANY OTHER PROVISION OF THIS TITLE
20 TO THE CONTRARY, THE COMMISSION MAY MODIFY LONG-TERM
21 CONTRACTS OR DISALLOW COSTS ASSOCIATED WITH CONTRACTS ENTERED
22 INTO PURSUANT TO A COMMISSION-APPROVED PROCUREMENT PLAN IF
23 THE COMMISSION DETERMINES THAT:
24 (I) THE CONTRACT DOES NOT COMPLY WITH THE
25 COMMISSION-APPROVED PROCUREMENT PLAN; OR
26 (II) THE CONTRACT ADVERSELY IMPACTS THE RATES OF A
27 CONSUMER DUE TO A CHANGE IN CIRCUMSTANCES.
28 (4) IF A CUSTOMER THAT CHOOSES AN ALTERNATIVE SUPPLIER
29 AND SUBSEQUENTLY DESIRES TO RETURN TO THE LOCAL DISTRIBUTION
30 COMPANY FOR GENERATION SERVICE, THE LOCAL DISTRIBUTION
20070S1134B2262 - 19 -
1 COMPANY SHALL TREAT THAT CUSTOMER EXACTLY AS IT WOULD ANY NEW
2 APPLICANT FOR ENERGY SERVICE.
3 (5) (I) NOTWITHSTANDING PARAGRAPH [(3)] (3.1), THE
4 ELECTRIC DISTRIBUTION COMPANY OR COMMISSION-APPROVED
5 ALTERNATIVE SUPPLIER MAY, IN ITS SOLE DISCRETION, OFFER
6 LARGE CUSTOMERS WITH A PEAK DEMAND OF [15] SEVEN
7 MEGAWATTS OR GREATER AT ONE METER AT A LOCATION IN ITS
8 SERVICE TERRITORY ANY NEGOTIATED RATE FOR SERVICE AT ALL
9 OF THE CUSTOMERS' LOCATIONS WITHIN THE SERVICE TERRITORY
10 FOR ANY DURATION AGREED UPON BY THE ELECTRIC DISTRIBUTION
11 COMPANY OR COMMISSION-APPROVED ALTERNATIVE SUPPLIER AND
12 THE LARGE CUSTOMER. THE COMMISSION SHALL PERMIT, BUT
13 SHALL NOT REQUIRE, AN ELECTRIC DISTRIBUTION COMPANY OR
14 COMMISSION-APPROVED ALTERNATIVE SUPPLIER TO PROVIDE
15 SERVICE TO LARGE CUSTOMERS UNDER THIS PARAGRAPH. CONTRACT
16 RATES ENTERED INTO UNDER THIS PARAGRAPH SHALL BE SUBJECT
17 TO REVIEW BY THE COMMISSION IN ORDER TO ENSURE THAT ALL
18 COSTS RELATED TO THE RATES ARE BORNE BY THE PARTIES TO
19 THE CONTRACT AND THAT NO COSTS RELATED TO THE RATES ARE
20 BORNE BY OTHER CUSTOMERS OR CUSTOMER CLASSES. IF NO COSTS
21 RELATED TO THE RATES ARE BORNE BY OTHER CUSTOMERS OR
22 CUSTOMER CLASSES, THE COMMISSION SHALL APPROVE THE
23 CONTRACT WITHIN 90 DAYS OF ITS FILING, OR IT SHALL BE
24 DEEMED APPROVED BY OPERATION OF LAW UPON EXPIRATION OF
25 THE 90 DAYS. INFORMATION SUBMITTED UNDER THIS PARAGRAPH
26 SHALL BE SUBJECT TO THE COMMISSION'S PROCEDURES FOR THE
27 FILING OF CONFIDENTIAL AND PROPRIETARY INFORMATION.
28 (II) FOR PURPOSES OF PROVIDING SERVICE UNDER THIS
29 PARAGRAPH TO CUSTOMERS WITH A PEAK DEMAND OF 20 MEGAWATTS
30 OR GREATER AT ONE METER AT A LOCATION WITHIN THAT
20070S1134B2262 - 20 -
1 DISTRIBUTION COMPANY'S SERVICE TERRITORY, AN ELECTRIC
2 DISTRIBUTION COMPANY THAT HAS COMPLETED ITS RESTRUCTURING
3 TRANSITION PERIOD AS OF THE EFFECTIVE DATE OF THIS
4 PARAGRAPH MAY, IN ITS SOLE DISCRETION, ACQUIRE AN
5 INTEREST IN A GENERATION FACILITY OR CONSTRUCT A
6 GENERATION FACILITY SPECIFICALLY TO MEET THE ENERGY
7 REQUIREMENTS OF THE CUSTOMERS, INCLUDING THE ELECTRIC
8 REQUIREMENTS OF THE CUSTOMERS' OTHER BILLING LOCATIONS
9 WITHIN ITS SERVICE TERRITORY. THE ELECTRIC DISTRIBUTION
10 COMPANY MUST COMMENCE CONSTRUCTION OF THE GENERATION
11 FACILITY OR CONTRACT TO ACQUIRE THE GENERATION INTEREST
12 WITHIN THREE YEARS AFTER THE EFFECTIVE DATE OF THIS
13 PARAGRAPH, EXCEPT THAT THE ELECTRIC DISTRIBUTION COMPANY
14 MAY ADD TO THE GENERATION FACILITIES IT COMMENCED
15 CONSTRUCTION OR CONTRACTED TO ACQUIRE AFTER THIS THREE-
16 YEAR PERIOD TO SERVE ADDITIONAL LOAD OF CUSTOMERS FOR
17 WHOM IT COMMENCED CONSTRUCTION OR CONTRACTED TO ACQUIRE
18 GENERATION WITHIN THREE YEARS. NOTHING IN THIS PARAGRAPH
19 REQUIRES OR AUTHORIZES THE COMMISSION TO REQUIRE AN
20 ELECTRIC DISTRIBUTION COMPANY TO COMMENCE CONSTRUCTION OR
21 ACQUIRE AN INTEREST IN A GENERATION FACILITY. THE
22 ELECTRIC DISTRIBUTION COMPANY'S INTEREST IN THE
23 GENERATION FACILITY IT BUILT OR CONTRACTED TO ACQUIRE
24 SHALL BE NO LARGER THAN NECESSARY TO MEET PEAK DEMAND OF
25 CUSTOMERS SERVED UNDER THIS SUBPARAGRAPH. DURING TIMES
26 WHEN THE CUSTOMER'S DEMAND IS LESS THAN THE ELECTRIC
27 DISTRIBUTION COMPANY'S GENERATION INTEREST, THE ELECTRIC
28 DISTRIBUTION COMPANY MAY SELL EXCESS POWER ON THE
29 WHOLESALE MARKET. AT NO TIME SHALL THE COSTS ASSOCIATED
30 WITH THE GENERATING FACILITY INTERESTS BE INCLUDED IN
20070S1134B2262 - 21 -
1 RATE BASE OR OTHERWISE REFLECTED IN RATES. THE GENERATION
2 FACILITY INTERESTS SHALL NOT BE COMMISSION-REGULATED
3 ASSETS.
4 (6) A DEFAULT SERVICE PLAN APPROVED BY THE COMMISSION
5 PRIOR TO THE EFFECTIVE DATE OF THIS SECTION SHALL REMAIN IN
6 EFFECT THROUGH ITS APPROVED TERM. AT ITS SOLE OPTION, THE
7 DEFAULT SERVICE PROVIDER MAY PROPOSE AMENDMENTS TO ITS
8 APPROVED PLAN THAT ARE CONSISTENT WITH THIS SECTION, AND THE
9 COMMISSION SHALL ISSUE A DECISION WHETHER TO ACCEPT OR REJECT
10 THE PROPOSED AMENDMENTS WITHIN NINE MONTHS OF THE DATE THAT
11 THE AMENDMENTS ARE FILED. IF THE COMMISSION FAILS TO ISSUE A
12 FINAL ORDER WITHIN NINE MONTHS, THE AMENDMENTS SHALL BE
13 DEEMED TO BE APPROVED AND THE DEFAULT SERVICE PROVIDER MAY
14 IMPLEMENT THE AMENDMENTS AS FILED.
15 (7) THE DEFAULT SERVICE PROVIDER SHALL OFFER RESIDENTIAL
16 AND SMALL BUSINESS CUSTOMERS A RATE THAT SHALL CHANGE NO MORE
17 FREQUENTLY THAN ON A QUARTERLY BASIS. ALL RATES SHALL BE
18 REVIEWED BY THE COMMISSION TO ENSURE THAT THE COSTS OF
19 PROVIDING SERVICE TO EACH CUSTOMER CLASS ARE NOT SUBSIDIZED
20 BY ANY OTHER CLASS.
21 SECTION 4. THIS ACT SHALL TAKE EFFECT IN 60 DAYS.
J12L66SFL/20070S1134B2262 - 22 -