BEFORE ^ V % THE PUBLIC UTILITIES COMMISSION OF OfflO - ^ / , ^ 4>
In the Matter of the Application of Ohio ^ Edison Company, The Cleveland Electric r \ ? J? P niuminating Company and The Toledo Case No. 10- L/oQfl -EL-SSO Edison Company for Authority to Establish a Standard Service Offer Pursuant to RC. § 4928.143 in the Form of an Electric Security Plan
APPLICATION
Ohio Edison Company, The Cleveland Electric Illuminating Company, and The
Toledo Edison Company (hereinafter collectively referred to as the "Companies"), by this
Application request regulatory authority to establish a standard service offer ("SSO")
pursuant to R.C. § 4928.141. As their SSO, and pursuant to and consistent with the
provisions of R.C. § 4928.143, the Companies propose to implement this comprehensive
electric security plan designed to provide stable pricing of energy services for their
customers, assure supplies of electricity, enhance distribution service, and promote
energy efficiency, economic development and job retention and support for low income
customers within their service areas. Time is of the essence; the Commission must act
quickly on this Application as such expedited approval will permit the Companies to
immediately proceed with implementing the competitive bidding process to take
advantage of historically low market prices for wholesale electric generation, to the
benefit of customers. As demonstrated on Attachment A to the attached Stipulation, with
approval by the Commission on May 5, 2010, the Companies will be able to undertake
the necessary steps to accommodate the auction beginning on July 13, 2010.
i-erecl i n t h e r e g u l a r course of b u s i n e s s ^ m m — D a t e Processed i S ^ l l O
The Companies' electric security plan is embodied in the attached Stipulation and
Recommendation, including the Attachments thereto ("Stipulation", the Companies' plan
hereinafter referred to as the *'ESP") which is incorporated by reference herein and as if
all of the terms and conditions set forth in such attachment are fully written here. The
Companies request that no party that was granted intervention m Case No. 09-906-EL-
SSO need move to mtervene in this proceeding in order to be deemed a party hereto, and
that no attorney who was granted admission pro hac vice in Case No. 09-906-EL-SSO
need apply for admission pro hac vice in this proceeding in order to be deemed admitted
in this proceeding. As demonstrated by the number and diversity of signatory parties to
the Stipulation ("Signatory Parties"), the Companies believe that the vast majority of the
issues and concerns raised by the Signatory Parties have been addressed in the
substantive provisions of this Stipulation, and reflect, as a result of such discussions and
compromises by the Signatory Parties, an overall fair and reasonable resolution of such
issues. This Stipulation is the product of the discussions and negotiations of the
Signatory Parties, and accordingly, this Stipulation represents an accommodation of the
diverse interests represented by the Signatory Parties, and is entitled to careful
consideration by the Commission.
The ESP presents a broad and flexible approach that provides for the supply of
generation, but also allows for the inclusion of various provisions in an overall package
to address the broad range of issues contemplated within the scope of Am. Sub. S.B. 221.
The ESP has numerous quantitative and qualitative elements, carefully integrated into a
package which, taken in the aggregate, is considerably more favorable to customers than
the Market Rate Offer alternative. Further, the ESP addresses price issues from several
perspectives, including that: 1) it provides greata* price certainty over the ESP period; 2)
it settles pricing and service arrangements for the totality of electric service, not just
generation; 3) it provides substantial support for energy efficiency through targ^ed
support to several Signatory Parties; 4) it provides economic development fimding for
targeted major employers in the state of Ohio as well as a more general source of funding;
and 5) support for low income customers is provided in the form of continuation of the
Community Connections program and increased funding for the fuel fund, with all of the
foregoing remaining in place over the ESP period.
The Companies further request that the Commission take administrative notice of
the evidentiary record established in the Market Rate Offer ("MRO") filed by the
Companies, Case No. 09-906-EL-SSO, and thereby incorporate by reference that record
for the purposes of and use in this proceeding.
It is in the best interest of all parties that a timely ruling is made. Accordingly,
the Companies respectfully request that the Commission issue an order approving the
Stipulation and ESP, by May 5, 2010.
^ ^ d u U ^ les W. Burk, Coimsel of Record
Arthur E. Korkosz Mark A, Hayden Ebony L. Miller HRSTENERGY SERVICE COMPANY 76 South Main Street Akron, OH 44308
James F. Lang Laura C. McBride CALFEE, HALTER & GRISWOLD LLP 1400 KeyBank Center 800 Superior Ave.
Cleveland, OH 44114
David A. Kutik JONES DAY 901 Lakeside Avenue Cleveland, OH 44114
ATTORNEYS FOR APPLICANTS, OHIO EDISON COMPANY, THE CLEVELAND ELECTRIC ILLUMINATING COMPANY, AND THE TOLEDO EDISON COMPANY
BEFORE ^ - j ^%,
THE PUBLIC UTILITIES COMMISSION OF OfflO ^ / ^ t
In the Matter of the Application of Ohio ^ Edison Company, The Cleveland Electric *^ - r>^ Illuminating Company and The Toledo Case No. 10- Q O O Q -EL-SSO Edison Company for Authority to Establish a Standard Service Offer Pursuant to R.C. § 4928.143 in the Form of an Electric Security Flan
STIPULATION AND RECOMMENDATION
INTRODUCTION
Rule 4901-1-30, Ohio Administrative Code ("OAC") provides that any two or
more parties to a proceeding may enter into a written stipulation covering the issues
presented in such a proceeding. The purpose of this document is to set forth the
understanding and agreement of the parties who have signed below (the "Signatory
Parties") and to recommend that the Public Utilities Commission of Ohio (the
"Commission" or "PUCO") approve and adopt this Stipulation and Recommendation,
including all Attachments hereto, ("Stipulation"), as part of its Opinion and Order in this
proceeding, resolving all of the issues in the proceedings.
This Stipulation is supported by adequate data and information; represents a just
and reasonable resolution of issues in this proceeding; violates no regulatory principle or
precedent; and is the product of lengthy, serious bargaining among knowledgeable and
^ Although filed as "SSO" pursuant to R.C. § 4928.143 and to the Commission's Rules, we request that the proposal be considered as if filed pursuant to any other case designations as may be applicable to the scope of the proposals made herein.
capable Signatory Parties in a cooperative process and imdertaken by the Signatory
Parties representing a wide range of interests to resolve the aforementioned issues. Since
the Commission's Entry on November 12, 2009 in Case No. 09-906-EL-SSO directing
the Staff to submit comments related to the Companies' SSO or other SSO, and the filing
of Staff Cormnents on November 24, 2009 recommending that the Companies and
interested stakeholders pursue an Electric Security Plan ("ESP") as the Companies' SSO,
the Companies and numerous other parties have engaged in a wide range of discussions
over several months related to the competitive bidding process, recovery of transmission
related costs, distribution reliability and cost recovery, economic development in many
forms, energy efficiency, and support for low income customers, as well as the efficient
and timely resolution of other pending proceedings. This Stipulation represents the
culmination of these discussions and is an accommodation of the diverse interests
represented by the Signatory Parties, and it is entitled to careful consideration by the
Commission. For purposes of resolving the issues raised by this proceeding, the
Signatory Parties stipulate, agree and recommend as set forth below.
In the event the Commission does not approve this ESP as filed by Ohio Edison
Company ("Ohio Edison"), The Cleveland Electric Illuminating Company ("CEI")* and
The Toledo Edison Company ("Toledo Edison") (hereinafter individually and
collectively "Company" or "Companies") by May 5, 2010, then the Companies may
render this Stipulation and ESP null and void and the Application filed with this
Stipulation shall be considered withdrawn upon the fding of a written notice with the
Commission.
PARTIES
This Stipulation is entered into by and among the Staff of the Public Utilities
Commission of Ohio ("Staff'), the Companies and the other Signatory Parties hereto. All
the Signatory Parties have agreed to fully support the ESP filed in this proceeding as set
forth in this Stipulation.
RECITALS
WHEREAS, the Companies filed on October 20, 2009, an application for a
standard service offer ("SSO") pursuant to R.C. § 4928.141, which was assigned Case No.
09-906-EL-SSO. The application was for a market rate offer in accordance: with R.C. §
4928.142 (hereinafter the "MRO"). Following the filing of the application, extensive
discovery was conducted, a technical conference was held, testimony was filed on behalf
of the Companies, numerous interveners, and the Staff, hearings were held tiiat extended
over multiple days concluding on December 23, 2009, and briefs and reply briefs were
filed in the MRO proceeding.
WHEREAS, on November 12, 2009 an Entry was issued directing the Staff to
comment upon the Companies' proposed MRO. Staff timely filed comments on
November 24, 2009 addressing the Companies' MRO. Concurrently, Staff also
recommended that the Companies pursue an Electric Security Plan. In an effort to
facilitate such an undertaking, Staff issued a comprehensive framework containing
certain proposed terms and conditions of a proposed Electric Security Plmi. On
December 1, 2009, a prehearing conference was conducted with the parties to further
discuss the development and potential filing of an Electric Security Plan, At such time,
parties were provided an opportunity and encouraged to comment on Staffs proposal and
submit any recommendations. Subsequently, several conferences were held regarding the
filing and content of an Electric Security Plan, and following numerous additional
discussions among the Companies, the Staff, and other parties regarding the terms and
conditions of Staffs proposal and other terms and conditions as proposed by others, the
Companies filed an Electric Security Plan Application on March 23, 2010 in accordance
with R.C. § 4928.143 and the Commission's rules related thereto, with this Stipulation
attached thereto and incorporated therein;
WHEREAS, all of the related issues and concerns raised by the Signatory Parties
have been addressed in the substantive provisions of this Stipulation, and reflect, as a
result of such discussions and compromises by the Signatory Parties, an overall
reasonable resolution of all such issues. This Stipulation is the product of the discussions
and negotiations of the Signatory Parties, and is not intended to reflect the views or
proposals which any individual party may have advanced acting unilaterally.
Accordingly, this Stipulation represents an accommodation of the diverse interests
represented by the Signatory Parties, and is entitled to careful consideration by the
Commission;
WHEREAS, as proposed in die ESP, the impact upon customer bills will be
mitigated by the modifications to the charges and rate arrangements, as more fully
described in the ESP below, so that customers of the Companies will experience more
stable and certain rate levels than otherwise would have been in place during this period.
Through such modifications, customers will enjoy benefits that without the
implementation of the ESP would not have been made available;
WHEREAS, the ESP as set forth in this Stipulation represents a serious
compromise of complex issues and involves substantial customer benefits that would not
otherwise have been achievable. Through combining more certeun rate levels and timely
recovery of all amounts authorized by the PUCO to be collected through rate components
and deferral of cost recovery, the ESP provides electric service at more predictable prices
for an extended period, which would not have been available otherwise, all of which is
critical to the economy of Ohio and the well-being of Ohioans. The rates, together with
other terms and conditions provided in the ESP, better assure customers of stabilized
prices through the periods covered by the different aspects of the ESP and promote
energy efficiency, economic development and provide support for low income customers;
WHEREAS, the process set forth in R.C. § 4928.143 for an Electric Security Plan
shall be preserved.
WHEREAS, in order to address these and other concerns and provide customers
with assurances as to the price of electricity covered by the ESP during the three year
ESP period and provide energy efficiency, economic development, and low income
customer support, the Signatory Parties stipulate and agree to the ESP as set forth below.
NOW, THEREFORE, the Signatory Parties stipulate, agree and recommend tiiat
the Commission approve the ESP set forth in this Stipulation and issue its Opinion and
Order in accordance herewith, and recommend that the Commission act by May 5,2010.
A. Generation
1. For the period beginning Jime 1, 2011 and ending May 31, 2014, retail generation
rates will be determined pursuant to the results of a descending-clock format
competitive bid process, including any costs associated with administering tiie
procurement process, adjustments for losses and seasonality, and costs associated
with any necessary contingency process. In the competitive bid process, the
Companies will seek to procure, on a sHce of system basis, the aggregate
wholesale "full requirements" SSO Supply, which includes energy and capacity,
resource adequacy requirements, market-based transmission service and market-
based transmission ancillaries, to serve their retail SSO load and special contract
load for the period June 1, 2011 through May 31, 2014. The bidding process,
including its associated contingency process, shall be conducted by an
independent bid manager, CRA International. The Commission may also retain a
consultant who, in addition to other duties, may monitor the bidding process, the
cost of which will be included and recovered as part of the costs of procurement.
The independent bid manager has established a bidding schedule in conjunction
with the Companies, which is included as part of Attachment A. Bidding will
occur initially using three products of varying lengths and multiple bid processes
over the three year term of the ESP, as reflected in more detail in Attachment A.
All bidders, including FirstEnergy Solutions Corp. ("FirstEnergy Solutions"),
may participate subject to the limitations contained herein. As in previous
solicitations, suppliers must adhere to the bidding rules and enter into a SSO
Supply Agreement with the Companies. The competitive bid process shall be
conducted consistent with the process set forth in the MRO in Case No. 09-906-
EL-SSO, including without limitation: the (i) communication protocols; (ii) SSO
Supply Agreement; and, (iii) competitive bid process bidding rules, all as
modified to be in accord with this Stipulation and as more fully outlined in
Attachment A. CRA International will select the vanning bidder(s), but the
Commission may reject the results within forty-eight (48) hours of the conclusion
of the auction based upon a recommendation from the independent bid manager
or the Commission's consultant that the auction violated the competitive bidding
process rules in such a manner so as to invalidate the auction. The pricing
resulting from the outcome of the competitive bidding process shall be recovered
through Rider GEN. The winning bidder(s) wiU execute the SSO Supply
Agreement. Upon conclusion of an auction as set forth in Attachment A, the
auction manager, CRA International, and the Commission's consultant may
review the auction process and make recommendations to the Coromission and
the Companies as to process improvements for future auctions for delivery during
the term of this ESP. Based on the recommendations of the auction manager and
the Commission's consultant, the Commission may modify certain aspects of the
auction process of future auctions contemplated by this ESP. However, such
modifications may not alter the following: (1) all auctions are to be conducted as
descending clock auctions; (2) all auctions shall be on a slice of system basis; (3)
the load cap provisions contained in Section A. 10; (4) the auction process shall be
conducted to procure the entire SSO load requirements of the Companies
excluding the load associated with customers enrolled in PIPP as set forth below
in A.l; (5) product definition and credit parameters as contained hi the Master
Supply Agreement; and (6) tranche size. While PIPP customers will remain retail
generation customers of the Companies, their retail load and usage will be
excluded from the bid product and will instead be supplied by the Companies at a
six percent (6%) discount off the PIPP customers' price to compare. To
accomplish this pricing, the Companies will enter into a wholesale bilateral
contract with FirstEnergy Solutions for this power supply for a three year period,
with power flow imder such wholesale contract commencing June 1,2011. Under
the bilateral contract, FirstEnergy Solutions will supply power to the Companies
at wholesale in an amount sufficient to meet the requirements of all PIPP
customers taking service imder the Companies' tariffs and riders for generation
service. As contemplated under Commission rule, PIPP customer load and usage
is non-shoppable except as provided for in R.C. § 4928.54 if a better price is
obtained. Under the wholesale contract, FirstEnergy Solutions would supply the
same energy and capacity, resource adequacy requirements, market-based
transmission service and market-based transmission ancillaries as winning bidders
in the competitive bidding process. For purposes of this section, a PIPP
customer shall be defined as any customer who is a PIPP customer as of June 1,
2011 and any customer who thereafter is enrolled in the PIPP program during the
period of this ESP.
2. There shall be no minimum stay for residential and small commercial non-
aggregation customers.
3. There shall be no minimum default service rider or standby charges as proposed
by the Companies in Case No. 08-935-EL-SSO. There will be no rate
^ At this time, Constellation NewEnergy, Inc. and Constellation Energy Commodities Group, Inc. take no position regarding this specific provision of the Stipulation related to the pricing and source of power for PIPP customers but for purposes of Settlement support the Stipulation as a whole.
stabilization charges ("RSC"). Unless otherwise noted, all generation rates for the
ESP period are bypassable and there are no shopping credit caps.
4. Renewable energy resource requirements for the period June 1,2011 through May
31, 2014 (including overpurchasing Renewable Energy Credits ("RECs") m one
year for banking into the next year) will be met using a separate Request for
Proposal ("RFP") process to obtain RECs. The RFP process will be conducted by
an independent bid manager. The RFP will seek to procure the Companies'
renewable energy requirements for Solar - Ohio, Solar - Ohio and contiguous
states, Renewables - Ohio, and Renewables - Ohio and contiguous states. No
energy or capacity will be purchased under the RFP. Bidders must prove their
RECs are certified or in the process of becoming certified by the Commission.
If the Companies are unable to acquire the required number of RECs through the
RFP process, then the Companies may acquire the remaining needed RECs
through bilateral contracts.
The costs related to the procurement of all RECs, including any costs associated
with administering the RFP, will be included in Rider AER for recovery in the
year in which the RECs are utilized to meet the Companies' renewable energy
requirements, with any reconciliation between actual and forecasted information
being recognized through Rider AER in the subsequent quarter.
5. The rate design currently in effect remains in place other than as modified below.
However, the Commission may,,with the Companies' concurrence, institute a
changed revenue neutral distribution rate design:
i) The average total rate overall percentage increase projected for the period 12
months ending May 2012 (rates to be effective commencing June 1, 2011)
compared to 12 months ending May 2011 resulting fi-om the rates derived from
the Competitive Bid Process for customers on Private Outdoor Lighting, Traffic
Lighting, Street Lighting, and Rate GT rates shall not exceed a percentage in
excess of one and one-half times the system average overall percentage rate
increase (the "cap"), by Company. If the average percent change by Company is
negative, then no cap shall be applied. This cap calculation shall be performed
prior to June 1* each year. Recovery of any revenue over the cap stated above
shall be recovered under Provision (e) of Rider EDR.
ii) As a demand response program under R.C. § 4928.66, any revenue shortfall
resulting from the application of the $1.95 per kW/month interruptible credit in
the Rider OLR and the $5.00 per kW/month interruptible credit in the Rider ELR
will be recovered from all non-interruptible customers as part of the non-
bypassable demand side management and energy efficiency rider ("DSE") imder
the provisions of DSE-1;
iii) The seasonality factors as proposed in the Companies' MRO application, Case
No. 09-906-EL-SSO, shall be adopted in this proceeding,
iv) Capacity costs that result fi'om the PJM capacity auctions will be used to
develop capacity costs for Rider GEN. The PJM capacity costs from the auctions
for each year will be allocated to the Companies and to each tariff schedule for
each Company based on the average of the coincident peaks, including
distribution losses, for the months of June through September of the prior year.
10
The allocated capacity costs will be used to develop a kWh charge for each tariff
schedule under the capacity charge section of Rider GEN. The PJM capacity
costs auction resuUs at the wholesale level, converted to an energy basis, will be
subtracted from the auctions results under paragraph A.l of this Stipulation to
develop the non-capacity related energy charge for Rider GEN.'
v) Rate schedule RS will have a flat rate structure.
vi) The initial allocation of revenue responsibility associated with establishing
rates to recover the results of the competitive bid process for the Companies' rate
schedules Rate GS and Rate GP will be implemented so as to produce a
percentage increase, as compared to overall July 2010 rate levels, which is
approximately equal for the two schedules.
6. A Generation Service Uncollectible Rider, Rider NDU, shall be continued to
recover non-distribution related uncollectible costs associated with supply cost
fi-om the competitive bid process arismg fi*om SSO customers and shall only
apply to generation and transmission uncollectible costs arising fi-om SSO
customers and will be bypassable for customers that switch to a certified retail
electric service ("CRES") supplier, and shall be reconciled on a quarterly basis.
7. Rider GCR shall be avoidable by customers during the period that the customers
purchase retail electric generation service fi-om a CRES provider subject to the
following conditions:
a) If the allowed balance of Rider GCR reaches 5% of the generation expense, as calculated below on an illustrative basis, then this balance would shift to recovery through a non-avoidable charge in Rider GCR.
Annual MWh 55,000,000 Quarterly MWh 13,750,000
11
Shopping % Average Price Quarterly Rev Increase Cap Allowed Balance
50% 65 446,875,000 5% 22,343,750
b) In the event of a winning bidder default, pursuant to and as defined m the Master SSO Supply Agreement, the Companies may convert Rider GCR to a non-avoidable charge provision if they believe the bidder default will cause the GCR balance to exceed the 5% threshold established in subsection a) above.
8. The Signatory Parties acknowledge that the results of the Fixed Resource
Requirement ("FRR") capacity auctions will be available to the Commission by
the time the Commission issues its Order related to this Stipulation.*'
9. Recovery of costs through Rider DFC and Rider DGC may be accelerated if such
acceleration would be beneficial to customers and other Signatory Parties.
Signatory Parties will work together if such acceleration would be beneficial to
customers, and will file an application for such acceleration for approval by -the
Commission. Any Signatory Party that does not support acceleration of recovery
of these costs may oppose any application seeking Commission approval for such
acceleration. Rider DGC will not apply to customers who were served by CEI
under fixed price contracts during the period January 2009 through May 2009.
10. The Commission may order a load cap^ of no less than 80% on an aggregated
load basis across all auction products for each auction date such that any given
bidder may not win more than 80% of the tranches in any auction.
^ The FRR auction results for the 2011/2012 and 2012/2013 delivery years will not be known until the PJM Independent Market Monitor has concluded his review/analysis of all capacity offers during the week of March 13,2010. The capacity ch^-ges will, subject to the review of the Commission as part of this proceeding. To the extent that the Commission's review results in any impact on the Companies' ability to recover capacity charges, the Companies shall have the authority to declare tiiis entn^ ESP null and void and this ESP shall be withdrawn upon the filing of a written notice by the Companies.
12
B. Distribution
1. Except as expressly set forth elsewhere m this ESP, the Signatory Parties agree
that, during the ESP period, no proceeding will be commenced by the Signatory
Parties, and recommend that no proceeding be commenced by the Commission,
whereby an adjustment to the base distribution rates of the Companies would go
into effect prior to June 1, 2014 (subject to riders and other charges provided in
the tariffs), subject to the "significantly excessive earnings test", except in a case
of an emergency pursuant to the provisions of R.C. § 4909.16. Approval of the
Stipulation by the Commission indicates acceptance of the Signatory Parties'
recommendation. The Companies are not precluded during this period, however,
from implementing changes in rate design that are designed to be revenue neutral
or any new service offering, both as approved by the Commission.
2. Effective January 1, 2012, a new rider, hereinafter referred to as Rider DCR
("Delivery Capital Recovery"), will be established to provide the Companies with
the opportimity to recover property taxes, Commercial Activity Tax and
associated income taxes and earn a return on and of plant in service associated
with distribution, subtransmission, and general and intangible plants including
allocated general plant from FirstEnergy Service Company that supports the
Companies, which was not included in the rate base determuied in the Opinion
and Order of January 21, 2009 in Case No. 07-551-EL-AIR et al. ("last
"* The Signatory Parties acknowledge that it is the Companies' position that any load cap would violate the statutory provisions of R.C. § 4928.142 - MRO. ^ The CBP Manager believes that a load cap imposed on the competitive biddmg process is unnecessary, risks the level of bidding participation in the auction, and is detrimental to the bidding process and its objectives.
13
distribution rate case"). The return earned on such plant will be based on the cost
of debt of 6.54% and a return on equity of 10.5% determined in the last
distribution rate case utilizing a 51% debt and 49% equity capital structure. The
net capital additions included for recognition under Rider DCR will reflect gross
plant in service not approved in the Companies' last distribution rate case less
growth in accumulated depreciation reserve and accmnulated deferred income
taxes associated with plant in service since the Companies' last distribution rate
case. Rider DCR shall be adjusted quarterly to reflect in-service net capital
additions and encourage investment in the delivery system. For the first 12
months Rider DCR is in effect, the revenue collected by the Companies under
Rider DCR shall be capped at $150 million; for the following 12 months the
revenue collected by the Companies under Rider DCR shall be capped at $165
million, and for the following five months the revenue collected by the
Companies under Rider DCR shall be capped at $75 million. Consistent with the
time periods for the revenue caps established above, each individual Company
will have a cap of 50%, 70% and 30% for Ohio Edison, CEI and Toledo Edison,
respectively, of the total aggregate caps as established above. Capital additions
recovered through Riders LEX, EDR, and AMI, or any other subsequent rider
authorized by the Commission to recover delivery-related capital additions, will
be identified and excluded fi-om Rider DCR and the annual cap allowance.
Revenue requirements will be derived for each company separately, and on that
basis the recovery of the revenue among the classes of each Company will be
calculated using the same methodology as the existing DSI Rider.
14
To effect the quarterly adjustments, the Companies will submit a filing that
contains the adjustment requested, the resulting rate for each customer class and
the bill impact on customers. The filmg shall show the Plant in Service account
balances and accumulated depreciation reserve balances compared to that
approved in the last distribution rate case. The expenditures reflected in the filing
shall be broken down by the Plant in Service Accounts Numbers associated with
Accoimt Titles for subtransmission, distribution, general and intangible plant,
including allocated general plant from FirstEnergy Service Company that
supports the Companies based on allocations used in the Companies' last
distribution rate case. Net capital additions for Plant in Service for General Plant
shall be included in the DCR so long as there are no net job losses at the
Companies as a result of involuntary attrition as a result of the merger between
FirstEnergy Corp. and Allegheny Energy, Inc. For each account title the
Companies shall provide the plant in service and accumulated depreciation
reserve for the period prior to the adjustment period as well as during the
adjustment period. The filing shall also mclude a detailed calculation of the
depreciation expense and accumulated depreciation impact as a result of the
capital additions. The Companies will provide the information on an individual
Company basis.
The Signatory Parties agree that the quarteriy Rider DCR update filing will not be
an application to mcrease rates within the meaning of R.C. § 4909.18 and each
Signatory Party fiirther agrees it will not advocate a position to the contrary in any
future proceeding. The first quarteriy filing will be made on or about October 31,
15
2011, based on an estimated balance as of December 31, 2011 with rates effective
on January 1, 2012 on a bills rendered basis. Thereafter, quarterly filings will be
made on or about January 31, April 30, July 30, and October 31 with rates
effective on a bills rendered basis effective April 1, July 1, October 1, and January
I, respectively. The quarterly filings will be based on estimated balances as of
March 31, June 30 September 30, and December 31, respectively, with any
reconciliations between actual and forecasted information being recognized in the
following quarter. The Companies will bear the burden of proof to demonstrate
the accuracy of the quarterly filings. Staff and Signatory Parties shall at their
discretion conduct an annual audit, following the Companies' January 31, 2013
and January 31, 2014 filings, and one final audit following the Conrpanies' July
30, 2014 final reconciliation filing. Staff and Signatory Parties shall file thek
recommendations and/or objections within 90 days after the filing of the
application. If no objections are filed within 90 days after the filing of the
application, the proposed DCR rate will remain in effect without adjustment,
except through the normal quarterly update process. If the Companies are unable
to resolve any objections within 120 days of the filing of the application, an
expedited hearing process v H be established in order to allow the parties to
present evidence to the Commission regarding the conformance of the application
with this Stipulation.
For any year that the Companies' spending would produce revenue in excess of
that period's cap, the overage shall be recovered in the following cap period
subject to such period's cap. For any year the revenue collected under the
16
Companies' Rider DCR is less than the annual cap allowance, as established
above, then the difference between the revenue collected and the cap shall be
applied to increase the level of the subsequent period's cap. In no event will
authorization exist to recover in the DCR any expenditures associated with net
plant in service additions made after May 31,2014.
3. Any charges billed through Rider DSI prior to January 1, 2012 shall not be
included as revenue in the return on equity calculation for the Companies for
purposes of applying the Significantiy Excessive Earnings Test ("SEET"), nor
considered as an adjustment eligible for refimd. Any charges billed through Rider
DCR after January I, 2012 will be included as revenue in the return on equity
calculation for purposes of SEET and will be considered an adjustment eligible
for refimd. For each year during the period of this ESP, adjustments will be made
to exclude the impact: (i) of a reduction in equity resulting from any write-off of
goodwill, (ii) of deferred carrying charges, and (iii) associated with any additional
liability or write-off of regulatory assets due to implementing this ESP. The
significantly excessive earnings test applicable to plans greater than three years
and set forth in R.C. § 4928.143(E) is not applicable to this three-year ESP.
4. The Distribution Uncollectible Rider and the PIPP Uncollectible Rider may be
audited by an independent consultant or die PUCO Staff. The Commission shall
select and solely direct the work of the consultant. The Companies shall directly
contract for and bear the cost of the services of the consultant chosen by the
Commission. Staff will review and approve payment invoices submitted by the
consultant.
17
C. Transmission
1. NITS and other non-market-based FERC/RTO charges will be paid by utilities for
all shopping and nonshopping load, and the amount shall be recovered through
proposed Rider NMB, which is set forth in Attachment B. Under Rider NMB,
applicable costs will be allocated to the Companies and to each tariff schediile for
each Company based on the average of the coincident peaks including
distribution losses, for the months of Jtme through September of tiie prior year.
Winning bidders and retail suppliers would remain responsible for all other
FERC/RTO imposed or related charges such as congestion, market based
ancillary services and losses, which would be bypassable as part of Rider GEN.
2. All MTEP charges that are charged to the Companies, either directly or indirectly,
shall be recovered from customers through the rider discussed in C.l, above. The
Companies agree to not seek recovery through retail rates for MISO exit fees or
PJM integration costs from retail customers of the Companies. The Companies
agree to not seek recovery through retail rates for the costs billed by PJM during
the period June 1, 2011 through May 31, 2016 for RTEP projects which are
approved by the PJM Board prior to Jime I, 2011. In the event the Companies
receive any refimd or credit from PJM related to the charges described in the
preceding sentence, the Companies will retain all of the refimd or credit. All
other RTEP costs that are charged to the Companies, either directiy or indirectly,
shall be recovered from customers through the rider discussed in C.l, above.
Capacity costs shall be allocated as set forth in Section A.6.iv above and
recovered as set forth in Section A.l above. Approval of the Stipulation by the
18
Commission indicates acceptance of the Companies' authorization to recover the
costs described above in this paragraph. Signatory Parties to this ESP Stipulation
agree not to object to or otherwise contest in any forum the recovery by the
Companies of any of the charges they are entitled to recover pursuant to this
Section C.
3. On March 9, 2010, the Midwest ISO filed complaints against PJM in FERC
Docket No. ELI0-45 and ELI0-46 alleging errors on the part of PJM in
administering or implementing the congestion management process during the
period from 2005 to 2009. In the event that the final outcome of either or both
dockets calls for PJM to pay the Midwest ISO or member utilities of the Midwest
ISO, and PJM charges or attempts to charge the Companies for purposes of
funding such payment obligation, the Companies will not seek to recover such
PJM charges from their retail customers in Ohio. To the extent that the final
outcome of either or both dockets results in actual Midwest ISO charges or credits
to the Companies, such actual charges or credits will be reflected in Rider TAS.
4. As outlined in Attachment A and in this Section C, it is intended that shopping
and SSO customers shall be treated in the same maimer under Rider NMB. In the
event that CRES providers or other load serving entities (LSEs), in their capacity
in supplying retail customers in the Companies' service territories, receive an
invoice from PJM that contains charges or fees associated with RTEP charges that
conflicts with this provision, the Companies agree to cooperate with CRES
^ While the Companies will abide by the terms and conditions of this Section C, the Companies preserve the ability to argue that all RTEP charges are legally recoverable from customers in response to any challenges to the recovery of such charges, and the Companies making of such arguments does not constitute a position contrary to this Stipulation.
19
providers or other LSEs to dispute any such invoices through the applicable PJM
dispute resolution process.
D. Continuance of Existing Tariff Riders and Deferrals
The following provides a list of riders and deferrals that are either new, existing that
remain unchanged, or modified pursuant to this ESP. Such riders shall be subject to
ongoing Commission Staff review and audit.
I. The following tariff riders will remain in effect under their current terms and
conditions, including carrying charges as established in Case No. 08-935-EL-
SSO , and under the terms and conditions as approved in Case No. 08-935-EL-
SSO, except certain changes to end dates as indicated below:
Rider DSM Rider DUN Rider PUR Rider LEX Rider AER Rider CDR Rider GPP Rider DRR Rider NDU Rider TAS
Rider DSI Rider DFC Rider RAR
Demand-Side Management (Residential Only) Distribution Uncollectible Rider PIPP Uncollectible Rider Line Extension Recovery Rider Alternative Energy Resource Rider CEI Delta Revenue Recovery Rider Critical Peak Pricing (Change end date to 5/31/14) Delta Revenue Recovery Rider Non-Distribution Uncollectible Transmission and Ancillary Service Delivery Service Improvement (which ends 12/31/11 pursuant to its terms) Deferred Fuel Cost Reasonable An'angement Rider
2. The following tariff riders will remain in effect modified as set forth on
Attachment B, with such modified tariffs approved as part of this ESP:
Rider ELR Rider EDR Rider GCR
^ Other existing Riders that were authorized in proceedings other than Case No. 08-935-EL-SSO are not listed here, but will remain in effect as approved.
20
Rider OLR Rider DSE^ Rider GEN Rider AMI Rider DGC Rider RTP
With respect to Riders ELR and OLR as modified herein, the Signatory Parties
agree for themselves and recommend that the Commission should fmd tiiat the
demand response capabilities of customers electing service under these Riders
shall count towards the Companies' compliance with the peak demand reduction
benchmarks as set forth in R.C. § 4928.66 as applied by the Commission's
applicable rules and regulations and shall be considered incremental to
interruptible load on the Companies' system that existed in 2008. Approval of the
Stipulation by the Commission indicates acceptance of the Signatory Parties'
recommendation. Customers wishing to be on Rider ELR will need to sign their
Addendum to the Contract for Electric Service within thirty (30) days of the date
this Stipulation is filed with the Commission signaling their commitment of their
demand response capabilities under Rider ELR to the Companies under the peak
demand reduction benchmarks for the term of their service under Rider ELR.
Redlined tariffs are attached to this Stipulation as Attachment B, reflecting the
changes that will be implemented on June 1, 2011 based upon Commission
^ Rider DSE also remains subject to and, except as otherwise provided in this Stipulation, will be amended to reflect any changes approved by the Commission in Case No. 09-1947-EL-POR, et. al. not inconsistent with the terms and conditions of this Stipulation. With respect to the DSE2 charge for Rate GT customers under Rider DSE as modified herein, nothing in this Stipulation affects the paties' rights in Case No. 09-1947-EL-POR et. al. or future cases to advocate and support alternative rate designs for the DSE2 charge applicable to Rate GT customers and the rate design for the DSE2 charge for Rate GT ultimately ordered by the Commission in such cases(s) shall be utilized for the DSE2 charge thereafter.
21
approval in this proceeding. Such tariffs as modified will go into effect, per the
terms of the tariff, upon the effective date of this ESP,
3. The following new tariff riders are attached as part of Attachment B, with such
new tariffs approved as part of this ESP:
Rider DCR
1 Rider NMB
Delivery Capital Recovery (Discussed in Section B.2, above.) Non-Market-Based Services (Discussed in Section ! C.1, above.)
4. All deferrals previously approved in Case Nos. 08-935-EL-SSO and 07-551-EL-
AIR et al. shall continue under the approved terms and conditions, with such
deferrals, except line extension deferrals, continuing through May 31, 2014, and
until fiill recovery of such deferrals is accomplished. Such storm damage
deferrals shall be dependent upon deferral criteria being agreed upon by the Staff
and the Companies, with such agreement being sought within thirty days of the
filing of this Stipulation.
E. Energy Efficiency/Demand Response, AMI & Smart Grid
1. The following issues in the Companies' proposal for cost recovery, Case No. 09-
1820-EL-ATA, for the Ohio site deployment of the smart grid initiative shall be
approved as set forth below. All other issues pending in that proceeding will be
decided in that proceeding.
i) Collected from customers of Ohio Edison, CEI and Toledo Edison,
exclusive of GT customers.
22
ii) All costs approved in Case No. 09-1820-EL-ATA associated with the
project will be considered incremental for recovery under Rider AMI.
iii) Recovery of the costs approved in Case No. 09-1820-EL-ATA shall be over
a ten (10) year period for recovery under Rider AMI. The recovery of costs
over a 10 year period is limited to this ESP and shall not be used as
precedent in any subsequent AMI & Smart Grid proceeding.
iv) Return on the investment shall be at the overall rate of return from the
Companies' last distribution rate case.
v) Rate base is defined as plant in service, depreciation reserve and
accumulated deferred income taxes.
vi) All reasonably incurred incremental operating expenses associated with the
project will also be recovered.
vii) The Companies agree that dining the tenn of this ESP the deployment of the
smart grid initiative will not include prepaid smart meters and that there will
be no remote discomiection for nonpayment without complying with the
requirements of O.A.C. 4901:1-18-05.
viii) The Companies shall not complete any part of the Ohio Site deployment that
the DOE does not match funding in an equal amount. Therefore cost
recovery from customers will remain at 50% of total project cost even if the
DOE reduces the funding.
2. The administrators, as were identified and as the Companies were permitted to
designate pursuant to Section E,6,i of the Stipulation in Case No. 08-935-EL-SSO,
and who are Signatory Parties, shall continue to be administrators through the
23
term of this ESP and, shall receive compensation based on terms as approved by
the Commission in Case No. 09-553-EL-EEC, or as may be approved in the
future by the Commission, The Companies may also name up to five additional
administrators for commercial and industrial programs. Notwithstanding, and in
lieu of the fixed monthly compensation provided pursuant to Case No. 09-553-
EL-EEC, the Companies will provide funding to the Association of Independent
Colleges and Universities of Ohio ("AICUO"), Ohio Hospital Association
("OHA") and the Ohio Manufacturer's Association ("OMA") for their roles as
energy efficiency administrators for completed energy efficiency projects in the
following amounts: AICUO - $50,000 in 2011, $25,000 in 2012, $25,000 in 2013,
and $25,000 in 2014; OHA - $25,000 in 2011, $50,000 in 2012, $50,000 in 2013,
and $25,000 in 2014; OMA - $100,000 in 2011, $100,000 in 2012, and $100,000
in 2013, with such amounts recovered through Rider DSE.
3. During the term of this ESP, the Companies shall be entitled to receive lost
distribution revenue for all energy efficiency and peak demand reduction
programs approved by the Commission. Such lost distribution revenues do not
include approved historical mercantile self directed projected. The Signatory
Parties agree that the collection of such lost distribution revenues by the
Companies after May 31, 2014 is not addressed nor resolved by the terms of this
Stipulation.
4. The Companies will continue funding the Commimity Connections program
under the same terms and conditions and amounts as set forth in Case Nos. 07-
551-EL-AlR, et. al. and 08-935-ELTSSO for the period of this ESP; provided.
24
however, that the amount may be increased as a result of the energy efficiency
collaborative approving such funding increase, and it being approved by the
Commission and fully recoverable through Rider DSE or other apphcable rider.
Ohio Partners for Affordable Energy ("OPAE") shall be paid out of the
commitment above an administrative fee equal to 5% of the program funding
payable annually on the first day of the program year.
5. An AICUO college or university member may elect to be treated as a mercantile
customer, and the Companies will treat any such college or university as a
mercantile customer for the limited purposes of R.C. § 4928.66 so long as the
aggregate load of facilities situated on a campus and owned or operated by the
respective college or university qualifies such an entity as a mercantile customer
and makes the college or university eligible for any incentive, program, or other
benefit made available to a mercantile customer pursuant to R.C. § 4928.66.
6. AICUO will work cooperatively with the Companies to determine whether its
members have professionals capable of performing energy related research for the
benefit of the Companies and customers in achieving statutory energy efficiency,
demand response, and renewable energy benchmarks.
7. To help make energy efficiency programs available to Cleveland residents in the
CEI service territory and to enable the City of Cleveland to achieve its energy
efficiency and sustainability goals, the Companies will provide fimding to the
City of Cleveland to be used only for the benefit of CEI customers m the City of
Cleveland in the following amounts: $100,000 in 2011; $100,000 in 2012; and
$100,000 in 2013, with such amounts recovered through Rider DSE.
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F. Economic Development and Job Retention
1. During the period June 1, 2011 through May 31, 2014, the Companies will
contribute, in the aggregate, $3 million to support economic development and job
retention activities within their service areas, including without limitation to fund
customer-owned transformers, redundant feeds, and substations that improve
overall performance. The Companies agree not to seek recovery of such amounts
from customers. Such contribution shall not be used to fund special contracts
and/or reasonable arrangements filed with the Commission.
2. The Signatory Parties acknowledge and recognize that The Cleveland Clinic
Foundation (the "Clinic") anticipates implementing a major expansion plan at its
Main Campus located at 9500 Euclid Avenue in Cleveland, Ohio.' The Clinic's
current expansion plan calls for the Clinic to invest $1.4 billion in the Main
Campus to meet growing local, national and international patient demand and to
increase direct employees in Ohio by adding more than 1000 new high-quality
jobs in Cleveland, Ohio. ^ The current expansion plan will also create hundreds of
indirect and local construction jobs. The Clinic's expansion plan caimot be
successfully completed without alterations and modifications to the dectric plant,
facilities and equipment that have historically provided service to the Clinic and
other customers in the area. Such alterations and modifications include the design,
construction and operation of trmisformation and delivery plant, facilities and
equipment required to meet expected growth in the area in and around the Main
' At this time, the Ohio Hospital Association takes no position regarding this specific provision of the Stipulation relating to the Cleveland Clinic, but for purposes of this settlement supports the Stipulation as a whole, ^ The Clinic employs more than 40,000 direct employees in Northeast Ohio and is one of the largest private employers in Ohio.
26
Campus and to meet the reliability needs of the Clinic and its patients. Absent the
opportimity presented by this ESP proceeding, the Clinic, a mercantile customer,
intended to file an application for a reasonable arrangement for the purposes of
addressing the responsibility for the costs of the electric utility plant, facilities and
equipment that must be installed to allow the Clinic to successfiiUy complete its
expansion plan at its Main Campus and to address opportunities for the Clinic to
commit its energy efficiency, peak demand reduction or alternative energy
resource capabilities to CEI for purposes of meeting the portfolio requirements set
forth in R.C. § 4928.66. As a result of the intent to apply for approval of a
reasonable arrangement, the Clinic has discussed its expansion plan^ the electric
utility infi-astructure requnements and its customer sited capabilities with the Staff
of the Commission. In view of the foregoing and the desire to use this ESP
proceeding to comprehensively and timely address the issues and opportunities
related to the planned expansion of the Clmic's Main Campus, the Signatory
Parties hereby recommend that the Commission adopt all of the following
provisions as part of the ESP with the understanding that the Clinic shall proceed
with the above described Main Campus expansion plan upon such adoption by the
Commission:
• CEI shall be responsible for the cost of the electric utility plant, facilities and equipment installed to reliably support the Clinic's expansion plan at the Main Campus to the extent that such cost might otherwise be demanded by CEI from the Clinic in the form of a contribution in aid of construction or otherwise.
• CEI shall be entitied to classify the original cost of investment made in utility plant, facilities and equipment at or below the subtransmission level to support the Clinic's expansion plan as distribution plant in service subject to the Commission's jurisdiction for ratemaking purposes at the time of the next base rate case.
27
» The first seventy million dollars of the original cost of such plant, facilities and equipment shall be ftmded by a non-bypassable distribution rider that shall apply to the retail residential, commercial and mdustrial customers respectively (exclusive of customers on STL, TRF, POL rate schedules). The seventy million dollars will be depreciated and recovered, mcluding appropriate taxes, fi'om customers of the Companies over a five year period on a service rendered basis starting June 1,2011. Recovery shall be through Provision (g) of Rider EDR.
• The Clinic shall be obligated to work in good faith to install cost-effective energy efficiency measures in its facilities, with, where needed, the assistance of an independent energy facility auditor selected by the Clinic with input fi-om the Companies and the Commission's Staff. The customer-sited capabilities of the Clinic shall be counted, measured and verified by a qualified independent third-party evaluator (in the event there are not suitable alternatives to satisfy the counting, measurement and verification objectives) for R,C. § 4928.66, compliance purposes by using a whole building, total energy approach such as that used for purposes of benchmarking performance through the Portfolio Manager program operated under the supervision of the United States Environmental Protection Agency. This section F.2 shall apply to the entire customer-sited capabilities of the CHnic within the Companies' certified service areas as if the Clinic were a single account and in order to avoid suboptimization of resources. The Clinic shall work with the Companies and the Commission's Staff for the purposes of committing its new customer-sited capabilities to the Companies for integration into their R.C. § 4928.66, compliance benchmarks in exchange for the Companies investment in the distribution utility plant, facilities, and equipment over the five-year period. During such five-year period, nothing herein shall preclude the Clinic from seeking Commission approval of terms and conditions that are designed to encourage the Clinic to undertfdce and commit new customer-sited capabilities to the Companies. After such five-year period, the Clinic shall have unimpaired access to utility and other energy efficiency, peak demand reduction and alternative energy programs open to mercantile customers,
3. This provision applies for the period of the ESP to domestic automaker facilities
that used more than 45 million kWhs annually at a single site in 2009. For each
facility a baselme energy consumption level will be established based on the
average monthly consumption for the year 2009. On a monthly basis, usage
above the established baseline during the term of the ESP shall receive a non-
bypassable discount based on the following:
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- For the first 10% increment of usage above the baseline a discount of 1.0 cents/kWh will be provided;
- For the second 10% increment of usage above the baseline a discount of 1.0 cents/kWh will be provided; and
- For all additional usage above the baseline a discoimt of 1.2 cents/kWh will be provided
Any discotint provided shall be collected based on a levelized rate for all three
Companies under Rider EDR from customers provided service under the RS, GS,
GP and GSU rate schedules.
4. CEI agrees to establish a LED streetlight pilot program ("LED Pilot") for die City
of Cleveland for the period of this ESP subject to the following terms and
conditions:
a. The LED Pilot is applicable to LED streetlights installed by the City of Cleveland during the period of this ESP.
b. The City of Cleveland will be billed the base distribution charges of the CEI Customer Owned Streetiight rate based on March 2010 kWh usage. No reduction in kWh usage shall be applied to base distribution charges as a result of the City of Cleveland's LED Pilot.
c. CEI will work in good faith with the City of Cleveland to develop monthly kWh usage for the different types and sizes of LED streetiights being installed at such time as the City of Cleveland has identified the applicable LED streetlight project.
d. The City of Cleveland must provide CEI a written report detailing the number of streetlights installed with LED lighting and the location of such installations. CEI will have 30 days from receiving such report to verify that the LED streetiights have been installed. The City of Cleveland will then be billed for all other charges and riders based upon an agreed monthly kWh usage figure starting at the next billing date following the verification. Over at least a 30 day period, which may occur prior to the start of the ESP, the City of Cleveland will measure the consumption of each type of LED streetiight it will install. This information will be shared with CEI to help determine the basis for the "agreed upon monthly kWh usage" for ihe particular LED streetiight.
G. Retail Market Enhancements
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The Companies agree to provide enhanced customer data and information and web-
based access to such information by June 1, 2011, subject to and consistent with the
Commission's rules, as set forth in Attachment C.
H. Other Issues
1. The Companies' corporate separation plan in Case No. 09-462-EL-UNC shall be
approved as filed. However, within six months after the completion of the merger
between FirstEnergy Corp. and Allegheny Energy, Inc. or within 18 months after
this Stipulation is approved, whichever comes first, if the Companies' corporate
or operational structure has changed, then tiie Companies shall file an updated
corporate separation plan. In either case whether an updated corporate separation
plan is filed or not, this plan may be audited by an independent auditor. The
Commission shall select and solely direct the work of the auditor. The
Companies shall directly contract for and bear the cost of the services of the
auditor chosen by the Commission. Staff will review and approve payment
invoices submitted by the consultant.
2, The Companies will file a separate application to commence recovery of any new
or incremental taxes arising after June 1, 2011, whether paid by or collected by
the Companies, and not recovered elsewhere, the recovery of which is
contemplated by this Stipulation. The recovery mechanism and procedural
schedule will be determined by the Commission at the time the Commission
approves the Companies' application. The application will be deemed approved
if the Commission has not ruled to the contrary within 90 days of the filing. The
recovery of such taxes would be subject to a Staff audit.
30
3. Time differentiated pricing concepts as proposed by the Companies and approved
by the Conunission m Case No. 09-541-EL-ATA shall continue in effect tirough
the term of this ESP, In addition, the auction bidding rules will not prohibit any
new time differentiated pricing concepts from being developed during the term of
this ESP.
4. The Signatory Parties agree for themselves, and recommend to the Commission,
to withdraw from FERC cases FirstEnergy Service Co. v. PJM, Docket No. ELIO-
6-000 and American Transmission Systems, Inc. ER09-1589-000, and that the
Commission should close Case No. 09-778-EL-UNC. Approval of the Stipulation
by the Commission indicates acceptance of the Signatory Parties'
recommendation.
5. With respect to the recent announcement of the combination of FirstEnergy Corp.
and Allegheny Energy, Inc., the Signatory Parties agree that the Commission
should not assert jurisdiction and review the merger, and further agree and
recommend that the Commission should not in this instance initiate its own
review of the merger in light of the facts that the merger is the result of an all
stock transaction and there is no change in control of the Companies. ' Approval
of the Stipulation by the Commission indicates acceptance of the Signatory
Parties' recommendation.
6. This ESP is more favorable in the aggregate to customers as compared to the
expected resuUs that would otherwise occur under an MRO alternative and
'' At this time, Constellation NewEnergy, Inc. and Constellation Energy Commodities Group, Inc. take no position regarding this specific provision of the Stipulation and expressly reserve all rights regarding wy proceedings before the FERC or any other regulatory body other than the PUCO regarding the proposed combination of Fu-stEnergy and Allegheny but for purposes of Settlement support the Stipulation as a whole.
31
represents a serious compromise of complex issues and involves substantial
customer benefits that would not otherwise have been achievable. Through
combining more certain rate levels and timely recovery of all amounts authorized
by the Commission to be collected through rate components and deferral of cost
recovery, this ESP provides electric service at more predictable prices for an
extended period and promotes energy efficiency, economic development and
provides support for low income customers, which would not have been available
otherwise, all of which is critical to the economy of Ohio and the well-being of
Ohioans. ^
7. $1.5 million dollars will be made available to OPAE for its fuel fund program,
allocated as $500,000 in 2012, $500,000 in 2013, and $500,000 in 2014. Any
amounts not expended as part of the OPAE fuel fund program in the time frame
specified will not be carried forward.
8. If this ESP is inconsistent with the Commission's rules, the Companies request
waivers of those rules to the extent that the Commission deems necessary to
approve and implement this ESP.
' Constellation New Energy and Constellation Energy Commodities Group take no position on the relative value of an MRO in this case, but support the Stipulation as a whole.
32
H. Procedural Aspects
In the event the Commission does not approve this ESP as filed by the Companies
by May 5, 2010, then the Companies may render this Stipulation and ESP null and void
and the Application filed with this Stipulation shall be considered withdrawn upon the
Companies filing a written notice with the Commission.
The Application and ESP are presented, collectively, by all three Companies and
its offer is conditioned on its acceptance in its totality with all of its provisions and
accepted for all three Companies. The Commission's approval of the Stipulation
indicates the Commission's acceptance of all of the Signatory Parties' recommendations
contained herein.
The term of this ESP is June 1, 2011 to May 31, 2014. The duration of this ESP
(including for purposes of determining the applicability of R.C. § 4928.143(E)) is the
period during which the standard service offer provided by it is in effect, i.e., June 1,
2011 through May 31, 2014, which will be the termination date, except that certain
provisions will continue after May 31,2014 to the extent such provisions are necessary to
carry out the terms and conditions of tiie ESP. The Signatory Parties agree to not take a
position contrary to the preceding sentence in any forum. Approval of the Stipulation by
the Commission shall constitute its concurrence with this position. The Signatory Parties
request that the Commission take administrative notice of the evidentiary record
established in die MRO, Case No. 09-906-EL-SSO, and thereby incorporate by reference
that record for the purposes of and use in tiiis proceeding.
To the extent necessary, the terms and conditions of this ESP may require FERC
approval or a general affiliate waiver. The ESP is conditioned upon all necessary FERC
approvals to carry out the terms and conditions of matters set forth herein and
33
FirstEnergy Solutions being able to provide power and effectively participate in the
competitive bid process as contemplated by Section A.1 hereof
This Stipulation is submitted for purposes of this proceeding only, and is not
deemed binding in any other proceeding, and except as otherwise provided herein, nor is
it to be offered or relied upon in any other proceedings, except as necessary to enforce the
terms of this Stipulation. The agreement of the Signatory Parties reflected in this
document is expressly conditioned upon its acceptance in its entirety and without
alteration by the Commission. Notwithstanding anything herem to the contrary, the
Companies have the right to withdraw and terminate the Application and the ESP if the
Commission or any court of competent jurisdiction, rejects all or any part of the ESP or
otherwise modifies its terms or provisions. The Signatory Parties agree that if the
Commission or any court of competent jurisdiction rejects all or any material part of this
Stipulation, or otherwise materially modifies its terms, any adversely affected Signatory
Party shall have the right to file an application for rehearing or a motion for
reconsideration. If such application or motion is filed, and if the Commission or court
does not, on rehearing or reconsideration, accept the Stipulation without material
modification within 45 days of the filing of such motion, then anytime thereafter the
adversely affected Signatory Party may terminate its Signatory Party status without
penalty or cost and regain its rights as a non-Signatory Party as if it had never executed
the Stipulation by filing a notice with the Commission and tiie other Signatory Parties.
The provisions of this Paragraph do not impair the right of tiie Companies to withdraw
and terminate the ESP at any time prior to approval of the Application and ESP by the
Commission.
34
Unless the Signatory Party exercises its right to terminate its Signatory Party
status as described above, each Signatory Party agrees to and mil support the
reasonableness of the ESP and this Stipulation before the Commission, and to cause its
counsel to do the same, and in any appeal from the Commission's adoption and/or
enforcement of the ESP and this Stipulation. The Signatory Parties also agree to urge the
Commission to accept and approve the terms hereof as promptiy as possible.
35
IN WITNESS WHEREOF, this Stipulation and Recommendation has been signed
by the authorized agents of the undersigned Parties as of this J j ^ day of
/K t/ U'' ^ ^ , 2010. The imdersigned Parties respectfully request the
Commission to issue its Opinion and Order approving and adopting the ESP as set forth
in this Stipulation. The Stipulation will be held open for additional interveners and
parties to sign on as Signatory Parties until the issuance of an Order by the Commission.
the Public Utilities Commission of Ohio
A^ / ^ ^ p * ^ - ^ ^ - ^ -
IndusSMinergy Users - Ohio
io Edison Company Ohio Energy Group
C 4 ^ Z ^ ^ z t ^ t ^ —
oledo Edison Company
A ^ / ^ Z € ^ ^ u / ^
K Cleveland Electric lluminating Company
, ^ v Ohio Hospital Association
The Association of Indep and Universities of Ohio
Ohio Partners for Affordable Energy CJ
Ohio Schools Council
Nucor Steel, Marion, Inc. / / ^ / feity of Cleveland J ^ ^ - rA-w
--- ,- Y
Material ~ k e n c e s Corporation
7 L o ID& b y E(*H W~l" .~ l '
Ohio Manufacturers' Association
Constellation New Energy, Inc. Constellation Energy Commodities Group, Inc.
PJM power Providers ~ r o u ~
Attachment A
Overall changes will need to be made to documents proposed for use in the Companies' MRO - Case No. 09-906-EL-SSO - including die Master SSO Supply Agreement, Competitive Bidding Process Rules and Communication Protocols, to conform them to the language contained in the Stipulation and to reflect that the requirements of R.C. § 4928.142 shall not apply to the bidding process.
Specific modifications will need to be made as follows:
1. Previously Approved Alternate Forms of Guaranty A potential bidder that had secured approval for an alternate form of guaranty for the 2009 Ohio CBP and that wishes to use the same alternate form of gtiaranty can renew this approval for any CBP conducted pursuant to the ESP hi Case No. XX-XXX-EL-SSO (tile "ESP CBP"), by submitting: DThe alternate form of guaranty for the 2009 CBP; DThe enforceability opinion for tiie 2009 CBP; DA certification tiiat the text of the alternate form of guaranty for the ESP CBP is exactly the same as the alternate form of guaranty tiiat had been previously approved for tiie 2009 CBP; DA certification that the text of the enforceability opinion for the ESP CBP is exactiy the same as the enforceability opinion that had been previously approved for tiie 2009 CBP.
If a potential bidder submits the materials as specified above, the alternate form of guaranty will be approved for the ESP CBP without further re-evaluation. If a potential bidder had secured approval for an alternate form of guaranty for the 2009 CBP but is unable to provide the materials as specified above, the potential bidder must resubmit the alternate form of guaranty and all supporting documentation as specified in the Minimum Requirements for the Altemate Form of Guaranty section above and these materials will be re-evaluated giccording to the criteria set forth in this document.
2. Attachment B, CBP Schedule and Timeline, to the MRO Application will be modified as follows -
38
Si S
^
1 ?
o
1 ^
1 ^
TJ O x: o
a. m o
Ui
CBP Timeline
Proposed Timeline for the 2010 Competltve Procwrement Auct oris Auction Activity Date Auction 1
Information Session #1 Deadline: CRA announces tranche target and tranche size (% and MW} Information Session #2 Deadline to submit Part 1 AppBcations Information Session #3 (if needed) information Session #4 (if needed) ' Deadline: CRA announces any update to the tranche size (MW) Deadline to submit Part 2 Applications Bidder User Manuals Distributed Mock Auction for Registered Bidders Deadline: CRA announces starting price to Registered Bidders Auction for Registered Bidders CRA notifies Companies and PUCO of results SSO Master Agreements Signed
Information Session #1 Deadline: CRA announces tranche target and tranche ^ze (% and MW) Information Session #2 Deadline for Bidders to submit new or updated Part 1 AppBcations Information Session #3 (if needed) Information Session #4 (if needed) Deadline: CRA announces any update to the tranche size (MW) Deadline to submit Part 2 Applications Bidder User Manuals Distributed MocK Auction for Registered Bidders Deadline: CRA announces starting price to Registered Bidders Auction for Registered Bidders CRA notifies Companies and PUCO of results SSO Master Agreements Signed
Power Flow
Thursday, April OB, 2010
Thursday, April 15,2010 Friday. April 23.2010 Friday, April 30, 2010
Tuesday, May 18,2010 Thursday, June 03,2010
Wednesday, June 09.2010 Wednesday. June 09.2010
Tuesday, June 15,2010 Wednesday, June 30,2010
Thursday. July 08.2010 Thursday, July 08,2010 Tuesday. July 13,2010 Tuesday, July 13, 2010 Monday, July 19,2010
Friday. July 30,2010 Tuesday, August 10.2010
Friday, August 20,2010 Wednesday. August 25,2010
Thursday, September 0?. 2010 Wednesday, September 15,2010 Wednesday, September IS, 2010
Tuesday, September 21.2010 Wednesday. September 29.2010
Thursday. October 07,2010 Thursday, October 07,2010 Tuesday. October 12,2010 Tuesday. October 12.2010 Monday, October 18.2010
Wednesday, June 01.2011
3. Alternate Billing at PJM
PJM on a billing line item basis, allows for market participants to select an altemate market participant for billing purposes so long as there is agreement between the two market participants for such an arrangement to take place.
For example, Party A is serving SSO load in OH. In that SSO Agreement, it states that PJM billing line Item 1100 - Network Integrated Transmission Service (NITS) charges will be paid for by the EDC. This means that Party A is assigned a NITS responsibility for a specific load amount. Under normal circumstances at PJM, PJM wotild then bill Party A accordingly for the NITS service. Instead however, PJM bills the EDC on their invoice and Party A never sees the charge show up on Party A's invoice. The EDC does not own the NITS load responsibility -just the obligation to pay the bill on behalf of Party A. PJM sets up this arrangement as is evidenced in the SSO agreement signed by both parties. The EDC submit to PJM all SSO Agreements so all parties financial settlements would work this way.
Further, for CRES suppliers, so long as the CRES supplier signs up customers in the EDO's retail zone, the Supplier Tariff (including the Operating Agreement) explains the same type of billing arrangement with respect to specific PJM billing line items. All processes associated with CRES supplier registration with the EDC indicate that certain PJM billing line items will be the
40
responsibility of the EDC and not the CRES supplier. PJM can then in turn charge the EDC for services such as NITS while the CRES supplier is the entity responsible for all load-related charges except those that PJM transfers back to the EDC
Section 6.6 of the Master Supply Agreement should be amended as follows:
Credit Rating of the SSO Supplier
:^: , ; :S&P;, ; : , ;
BBB+ and above jBBB BBB-BB~ BB r^B-Below BB-
TT' : Moody's:,;;',
Baal and above Baa2 Baa3 Bal Ba2 Ba3 Below Ba3
^;i!:;.;;::;Fi^M:;:;::\;^;:
BBB+ and above BBB BBB~ BB-H BB BB-Below BB-
Maximum Credit Limit (calculated as the] lesser of the percentage of TNW and the Credit Limit Cap below) |
Existing Riders that will continue as part of this ESP, but with amendments, are attached hereto and made part of this Attachment B. The attached tariffs are set forth in Section D.2 of the Stipulation and are in redline form showing the changes.
42
Attachment C
Data access including EDI transaction information access posted via electronic data interchange-post; 867 historical usage and historical interval usage data; 867 monthly usage and interval usage data; transmission and capacity Peak Load Contributions in EDI transaction; meter read cycle information.
A quarterly updated sync-list should be provided to CRES providers on a confidential basis showing the accounts that are enrolled with the CRES provider (which would contain information such as service start date, bill method, and PLC values). Web-based system that provides electronic access to key customer usage and accoimt data that can be accessed via a supplier website that is updated quarterly and that presents data and information including: account numbers, meter numbers, names, service addresses and billing addresses including zip codes, email addresses, meter read cycle dates, meter types, interval meter flags, rate code indicators, load profile group indicators, PLC values (capacity obligations), 24 months of consximption data in kWh by billing period including on-peak and off-peak data; 24 months of demand data (in kW) by billing period; 24 months of interval data; default service indicators (if on default service); minimum stay dates (if applicable); and identifiers of whether customers are participating in budget plans.
43
CERTIFICATE OF SERVICE
This is to certify that the foregoing Application has been served upon all of the parties of record in Case No. 09-906-EL-SSO by electronic mail and by U.S. Mail, postage prepaid this 2 ^ day of March, 2010.
les W. Burk Senior Attorney
Service List
Public Utilities Commission of Ohio Robert Fortney Tammy Turkenton 180 East Broad St. 3"* Floor Columbus, OH 43215 E-inail: robert.fortneyfgjpuc.state.oh.us Tammy.turkentonfgJpuc.state.Qh.us
Richard C.Reese Ohio Consumers' Counsel 10 West Broad Street 18th Floor Columbus, OH 43215-3485 [email protected] poulos@ occ.state.oh.us reesefgtocc.state.oh.us
Richard Cordray Duane W. Luckey Thomas McNamee William L Wright Asst. Attorneys General Public Utilities Section 180 E. Broad St., 6th FL Columbus, OH 43215 E-mail: [email protected][email protected] wil!iam.wright(g)puc.state.oh.us
Ohio Energy Group (OEG) Michael L. Kurtz David F. Boehm Kurt J. Boehm Boehm, Kurtz & Lowry 36 East Seventh Street, Suite 1510 Cincinnati, OH 45202 mkurt2@ BKLlawfirm.com [email protected]
Kroger Co John W. Bentine Mark S. Yurick Matthew S. White Chester Wilcox & Saxbe, LLP 65E. State St., Suite 1000 Columbus, OH 43215 [email protected][email protected] mwhitefaJcwslaw.com
Ohio Environmental Council Barth E. Royer Nolan Moser Trent A Dougherty Bell &. Royer, LPA 33 South Grant Avenue Columbus, OH 43215 barthroyer@aoI .com [email protected][email protected]:
Ohio Consumers' Counsel Jeffrey L Small Gregory J. Poulos
Industrial Energy Users (lEU) Samuel C. Randazzo Lisa G. McAlister
Daniel J. Neilsen Joseph M. Clark McNees Wallace & Nurick LLC 21 East State St., 17* Floor Columbus, OH 432! 5 E;mail; [email protected][email protected] iclark@,mv^mcmh.com
Ohio Partners for Affordable Energy David C Rinebolt Colleen L. Mooney (OPEA) 231 West Lima Street PO BOX 1793 Columbus, OH 43215 E-mail: [email protected] cmoonev2 @columbus .rr.com
Nucor Steel Marion, Inc. Garrett A. Stone Michael K. Lavanga Brickfield, Burchetle, Rilts & Stone 1025 Thomas Jefferson Street. NW Eighth Floor, West Tower Washington, DC 20007-5201 E-mail: £as@bbrs!aw,com mkl(a),bbrslaw.com
Direct Energy Services, Inc, M Howard Petricoff Stephen M. Howard Vorys, Sater, Seymore and Pease, LLP 52 East Gay Street PO Box 1008 Columbus, OH 43216-1008 E-mail: mhpetricoff@ vorvs.com
Teresa Ringenbach Direct Energy Services, LLC 5400 Frantz Rd., Suite 250 Dublin, OH 43016 E-mail: teresa.ringenbach@directenfergv._com
Ohio Hospital Association Richard L Sites 155 E. Broad Street, 15* Floor Columbus, OH 43215-3620 Phone:(614)221-7614 Email: [email protected]
Thomas J O'Brien Bricker & Eckler LLP 100 S. Third St. Columbus, OH 43215 E-mail: [email protected]
Northwest Ohio Aggregation Coalition (NOAC) Toledo Leslie A. Kovacik 420 Madison Ave., Suite 100 Toledo, OH 43604-1219 Phone: 419.245.1893 Fax: 419.245.1853 E-mail: [email protected]
Neighborhood Environmental Coalition, Consumers for Fair Utility Rates, United Clevelanders Against Poverty* Cleveland Housing Networl(, The Empowerment Center of Greater Cleveland (Citizens Coialition) Joseph P. Meissner The Legal Aid Society of Cleveland 1223 West 6^ Street Cleveland, OH 44113 Phone: 216.687.1900 Email: [email protected]
Constellation Energy Commodities Group, Inc., and Constellation NewEnergy, Inc. M Howard Petricoff Stephen M. Howard Vorys, Sater, Seymore and Pease, LLP 52 East Gay Street PO Box 1008 Columbus, OH 43216-1008 E-mail: mhpetricoff@ vorys.com
Cynthia A. Brady David 1. Fein Constellation Energy Resources, LLC 550 West Washington Blvd., Suite 300 Chicago, IL 60661
The Ohio Manufacturers' Association Thomas J. O'Brien
Bricker & Eckler LLP 100 S. Thud St. Columbus, OH 43215 E-mail: [email protected]
Kevin Schmidt The Ohio Manufacturers' Association 33 Nortii High Street Columbus, OH 43215-3005 [email protected]
GEXA Energy - Ohio, LLC Dane Stinson Bailey Cavalieri LLC 10 West Broad Street, Suite 2100 Columbus, Ohio 43215 [email protected]
The City of Cleveland Robert J. Triozzi Steven L Beeler City of Cleveland Dept. of Law 601 Lakeside Ave., Room 106 Cleveland, OH 44114 E-mail: [email protected][email protected]
Citizen Power Theodore S. Robinson 2121 Murray Avenue Pittsburgh, PA 15217 Email: [email protected]
Ohio Schools Council, Glenn S. Krassen Matthew W. Warnock Bricker & Eckler LLP 1375 £.9^^ St., Suite 1500 Cleveland, OH 44114 Email: [email protected] mwamock@,bricker.com
NOPEC Glenn S. Krassen Matthew W. Warnock Bricker & Eckler LLP 1375 E. 9* St, Suite 1500 Cleveland, OH 44114 Email: [email protected] m wamockfa),bricker. com
Morgan Stanley Capital Group Inc. Douglas M. Mancino McDermott Will & Emory LLP 2049 Century Park East Suite 3800 Los Angeles, CA 90067-3218 Email: [email protected]
Gregory K. Lawrence
28 State Street McDermott Will & Emory LLP Boston, MA 02109 Email: [email protected]
Steven Huhman Morgan Stanley 2000 Westchester Ave. Purchase, NY 10577 E-mail: [email protected]
Natural Resources Defense Council, Henry W. Eckhart 50 West Broad Street, #2117 Columbus, Ohio 43215 henryeckhart@aQ] .com
Association of Independent Colleges and Universities of Ohio Gregory J. Dunn Christopher Miller Andre T Porter Schottenstein Zox & Dunn Co., LPA 250 West St. Columbus, OH 4321 5 E-mail: [email protected][email protected] aporter@szdxom
Duke Energy Ohio Amy Spiller Duke Energy Business Services, Inc. 221 E. Fourth St., 25 Fl. Cincinnati, OH 45202 B-mail: [email protected]
Duke Energy Retail Sales, LLC Michael D. Dortch Kravitz, Brown & Dortch, LLC 63 E. State St., Suite 200 Columbus, OH 43215 E-mail: [email protected]
PJM Power Providers Group M Howard Petricoff Stephen M. Howard Vorys, Sater, Seymore and Pease, LLP 52 East Gay St. PO Box 1008 Columbus, OH 43216-1008 E-mail: [email protected][email protected]
FirstEnergy Solutions Michael Belting Morgan Parke
The Toledo Edison Company _ _ _ ^ Original Sheet 124
Toledo. Ohio P.U.C.O. No. 8 Page 1^1
RIDER DCR Delivery Capital Recovery Rider
APPLICABILITY:
Applicable to any customer who receives electric service under the Company's rate schedules set forth below. The Delivery Capital Recovery Rider (OCR^ charges will apply, by rate schedule, effective for bills rendered beginning January 1. 2012. This Rider is not avoidable for customers who take electric generation seryice from a certified supplier.
RATE:
RS fall kWhs. per kWh)
G S foer kW of Billina Demand^
G P (per kW of Billina Demand!
G S U (perkVa of Billinq Demand!
x.xxxxi i
Sx.xxxx
Sx.xxxx
$ x.xxxx
PROVISIONS:
The charges set forth in this Rider recover costs associated with delivery plant investments made since the date certain in Case No. 07-551-EL-AIR. exclusive of any delivery plant investments being recovered elsewhere.
RIDER UPDATES:
The charges contained in this Rider shall be updated on a quarterly basis. No later than October 31st January 31st April 3Qth and July 3Qth of each year, the Company will file with the PUCO a request for approval of the Rider charges which, unless otherwise ordered by the PUCO. shall become effective or) a bills rendered basis on January 1st April 1st July 1st and October 1st of each year-
Filed pursuant to Order dated . in Case No. . before
The Public Utilities Commission of Ohio
Issued by: . President Effective: October 31. 2011
Ohio Edison Company Original Sheet 124
Akron. Ohio P.U.C-O.No.11 Pace 1 of 1
RIDER DCR Delivery Capital Recovery Rider
APPLICABILITY:
Appiicabte to any customer who receives electric sen/ice under the Company's rate schedules set forth below. The Delivery Capital Recovery Rider (DCR) charges will apply, by rate schedule, effective for bills rendered beginning Januan/1. 2012. This Rider is not avoiciable for customers who take electric generation service from a certified supplier. •
RATE:
RS fall kWhs, per kWh) X.XXXXCJ
GS (per kW of Billina Demandj $ X.XXXX
GP (per kW of Billinq Demand) $ X.XiQOC
GSU fper kVa of Billinq Demand) $ X.XXXX
PROVISIONS:
The charges set forth in this Rider recover costs associated with delivery plant investments made since the date certain in Case No. 07-551-EL-AIR. exclusive of any delivery pbnt Investments betna recovered elsewhere.
RIDER UPDATES:
The charges contained in this Rider shall be updated on a quarterly basis. No later than October 31st January 31st April 30th and July 30th of each year, the Company will file with the PUCO a request for approval of the Rider charges which, unless otherwise ordered by the PUCO. shall become:effective on a bills rendered basis on January 1st. April 1st July 1st and October 1st of each year-
Filed pursuant to Order dated . in Case No. . before
The Public Utilities Commission of Ohio
Issued by: . President Effective: October 31. 2011
The Cleveland Electric Illuminating Comoanv Original Sheet 124
Cleveland. Ohio P.U.C.O. No. 13 Page 1 of 1
RIDER DCR Delivery Capital Recovery Rider
APPLICABILITY:
Applicable to any customer who receives electric service under the Company's rate schedules set forth below. The Delivery Capital Recovery Rider (DCR) charges will apply, by rate schedule, effective for bills rendered beginning January 1, 2012. This Rider is not avoidable for customers who take elec1;nc generation service from a certified supplier.
RATE:
RS fall kWhs. per kWh) x.xxxx (
GS (per kW of Billing Demand) Sx.xxxx
GP fper kW of Billing Demand) Sx.xxxx
GSU (per kW of Billing Demand) Sx.xxxx
PROVISIONS:
The charges set forth in this Rider recover costs associated with delivery plant investments made since the date certain in Case No. 07-551-EL-AIR. exclusive of any delivers plant investments being recovered elsewhere.
RIDER UPDATES:
The charges contained in this Rider shall be updated on a Quarterly basis. No later than October 31st Januan/ 31st. April 30th and July 3Qth of each year, the Company will file with the PUCO a request for approval of the Rider charges which, unless otherwise ordered by the PUCO. shall become effective on a bills rendered basis on January 1st April 1st July 1st and October 1st of each year.
Filed pursuant to Order dated in Case No. before
Issued by:
The Public Utilities Commission of Ohio
President Effective: October 31. 2011
The Toledo Edison Company
Toledo, Ohio P.U.C.O. No. 3
Original Sheet 119
Page 1 of 2
RIDER NMB Non-Market-Based Services Rider
APPLICABILITY:
Applicable to' any customer who receives electric sen/ice under the Company's rate schedules. The Non-Market-Based Services Rider (NMB) charge will apply, by rate schedule, effective for service rendered as described below. This Rider is not avoidable for customers who take electric generation service from a certified supplier.
PURPOSE:
The Non-Market-Based Services Rider (NMB) will recover non-market-based costs, fees or charges imposed on or charged to the Company by FERC or a regional transmission organization, independent transmission operator, or similar organization approved by FERC including, but not limited to:ji),PJM Interconnection. L.LC. f"PJM")^charqes assessed under Schedule IJScheduling,^ Systern Control and^ Dispatch Service). Schedule 1A (Transmission Owner Scheduling. System Control and Dispatch Services), Schedule 2 (Reactive Supply and Voltage Control from Generation or Other Sources Services). "Network Integration Transmission Service fNlTSV under the PJM Agreements. Schedule 11 (Transitional Market Expansion Charge) and Schedule 12 (Transmission Enhancement Charge) of the PJM Tariff, and (ii) Midwest Independent Transmission System Operator. Inc. f'MlSO") Jran5m[ssion Expansion Pjan (MTEP) charges assessed under Schedule 26 of the MISO. Tariff, whether assessed directly bv M1S0„ " PJM or American Transmission Systems, Incorporated.^
Rider NMB may be updated: 1) to account for changes in existing non-market-based costs, fees or charges^ncl^}Jo_incIude_an7 npn-jnarket-based costs, fees_o_r charges thatwere not vetjn effect on the effective date of this Rider and/or~othefwise Frnposed on or chirked to the Company by FET?C or a regional transmission organization, independent transmission operator, or similar organization approved by FERC.
RATE:
The NMB charge for each rate schedule shall be calculated as follows:
, - - -] Formatted: Font! (Default) Arial, 10
^ 1 Formatted: Not Highlight
Formatted: Font: (Defeult) Arial, 10 Pt
Formatted: Font: (Default) Arial, 10 pt
Formatted; Font (Default) Arjal, ID pt
Formatted: Font (Oefauft) Arfal, 10 pt
Oeteted:, Sc edufoig. System Control and Dispatch Service, Reactive Supply and Voltage Contn l Service and Nettmrk Integration Traismisalon SewiCfts.TI
Deleted: or
NIVIB = NMBC-E
BU 1-CAT
^ e r e :
NMBC The amount of the Company's total projected Non-Market-Based Services-related costs for the Computation Period, allocated to each rate schedule.
-( Deleted; Page Break ^
The Computation Period over which NMB will apply shall be June 1 through May 31 of each year.
Starting June 1,2012, any netover-orunder-collectionofthe Non-Market-Based Services-related costs, including applicable interest, invoiced during the period from June 1, 2011 to March 31, 2012, allocated to rate schedules. Thereafter, E will be calculated for the 12-month period ending March 31 immediately preceding the Computation Period.
Filed pursuant to Order dated ^ In Case No. before
Issued by:
The Public Utilities Commission of Ohio
, President Effective: June 1,2011
The Toledo Edison Company Original Sheet 119
Toledo, Ohio P.U.C-0. No. 8 Page 2 of 2
RIDER NMB Non-Market-Based Services Rider
BU = Forecasted billing units for the Computation Period for each rate schedule,
CAT = The Commercial Activity Tax rate as established in Section 5751.03 of the Ohio Revised Code.
NMB charges:
RS (all kWhs, per kWh) X.XXJOt
GS'{per kW of Billing Demand} $ X.XXXX
GP* (per kW of Billing Demand) $ XXXXX
GSU (per kVa of Billing Demand) $ X.XXXX
GT (per kVa of Billing Demand) $ X.XXXX
STL (all kWhs, per kV^) X.XXXX
TRF (all kWhs, per kWh) X.XXXX|i
POL (all kV\/ s, per kWh) X.XXXX{i
* Separately metered outdoor recreation facilities owned by non-profit^ governmental and educational institutions, such as athletic fields, served under Rate GS or GP, primarily for lighting purposes, will be charged per the NMB charge applicable to Rate Schedule POL.
RIDER UPDATES:
The charges contained in this Rider shall be updated and reconciled on an annual basis. The Company will file v^th the PUCO a request for approval of the Rider NMB charges on or before May 1 of each year which, shall become effective on a service rendered basis on.june 1_through May 31 ofjhe subseguent year, unless otherwise ordered by the Commission.
Dieted: Rider NMB will be filetj wiUi the PubHc Utilities Comnnission of Ohio on or before May 1 of each year for rates efTectfve for senrice rendered
Filed pursuant to Order dated , in Case No. , before
The Public Utilities Commission of Ohio
Issued by: .President ' Effective: June 1,2011
Ohio Edisor Company
Akron, Ohio P.U.C.O. No. 11
Original Sheet 119
Page 1 of 2
RIDER NMB N0n-Market-Based Services Rider
APPLICABILITY:
Applicable to any customer who receives electric service under the Company's rate schedules. The Non-IWarket-Based Services Rider (NMB) charge will apply, by rate schedule, effective for service rendered as described below. This Rider is not avoidable for customers who take electric generation service from a certified supplier.
PURPOSE:
The Non-Market-Based Services Rider (NMB) will recover non-market-based costs, fees or charges imposed on or charged to the Company by FERC or a regional transmission organization, independent transmission operator, or similar organization approved by FERC including, but not limited to:ji}^JIVI Interconnection, L.L.C. f"PJM")^harges assessed under Schedule IfSchedulinOj^ System ControJ an(J Dispatch Sen/ice). Schedule 1A (Transmission Owner Scheduling. System Control and Dispatch Services). Schedule 2 (Reactive Supply and Voltage Control from Generation or Other Sources Services). "Network Integration Transmission Service (NITSr under the PJM Agreements. Schedule 11 (Transitional Market Expansion Charge) and Schedule 12 (Transmission Enhancement Charge) of the PJM Tariff, and (ii) Midwest Independent Transmission System Operator. Inc. ("MISO") Jransmission Expansion Plan ^ (MTEP) charges assessed under Schedule 26 of the MISQ Tariff^ whether as5e5sed_directly by MlSQ^ " PJM or American Transmission Systems. Incorporated.^
Rider NMB may be updated: 1) to account for changes in existing non-market-based costs, fees or charges^nd 2]to_include_an_v non-niarket-bas_eci_cQ^^^ effective date of this Rider and/or otherwise Hposed on or'charged to'lhe ComparTy by FERC or a regional transmission organization, independent transmission operator, or similar organization approved by FERC.
RATE:
The NMB charge for each rate schedule shall be calculated as foltows:
Formatted: Font; (Default) Artal, 10 pt Formatted: Not Highlight
Forraatted; Font (Default) Arial, 10 pt
Formatted: Font (Default) Arial, 10 pt
Formatted: Font (Default) Artal, 10
Formatted: Font: (Default) Arial, 10 _pt
Deleted:, Scheduflng, System Cor^i and Dispatch Service, Reactive Suppty and Voltage Cont^I Service and Networlt Integration Transmission Secvtees.Tf
Deleted: or
NMB = NMBC^E
BU
1
1-CAT
^here:_ __
NMBC = The amount of the Company's total projected Non-Market-Based Services-related costs for the Computation Period, allocated to each rate schedule.
The Computation Period over which NMB will apply shall be June 1 through May 31 of each year.
Starting June 1, 2012, any net over- or under-collection of the Non-Market-Based Services-related costs, including applicable interest, invoiced during the period from June 1. 2011 to March 31. 2012, allocated to rate schedules. Thereafter, E will be calculated for the 12-month period ending March 31 immediately preceding the Computation Period.
'[Deleted; Page Break-
Filed pursuant to Order dated tn Case No. before
Issued by:
The Public Utilities Commission of Ohio
. President Effective; June 1.2011
Ohio Edison Company Original Sheet 119
Akron. Ohio P.U.C.O. No. 11 Page 2 of 2
RIDER NMB Non-Mark&t-Based Services Rider
BU = Forecasted billing units for the Computation Period for each rate schedule.
CAT = The Commercial Activity Tax rate as established in Section 5751.03 of the Ohio Revised Code.
NMB charges:
RS (all kWhs. per kWh) X.)OOO(0
GS* (perkW of Billing Demand) * $ X.XXXX
GP* (per kW of Billing Demand) $ X.XXXX
GSU (per kVa of Billing Demand) $ X.XXXX
GT (per kVa of Billing Demand) $ XXXXX
STL (all kWhs, per kWh) X.XXXX
TRF (all kWhs, per kWh) X.XXXX0
POL (ail kwns, par kWh} X.XXXX0
• Separately metered outdoor recreation facilities owned by non-profit^ governmental and educational institutions, such as athletic fields, served under Rate GS or GP, primarily for lighting purposes, will be charged per the NMB charge applicable to Rate Schedule POL.
RIDER UPDATES:
The charges contained in this Rider shall be updated and reconciled on an annual basis. The Company will file with the PUCO a request for approval of the Rider NMB charges on or before May 1 of each year which, shall become effective on a service rendered basis on June 1 through May 31 pfjhe subseqtient _ _ _ - - ^ Deleted: Rider NMB WHI be tiled wm year, unless otherwise ordered by the Commission. ~ ^^ ^'^^^ utnaies Commissjon of
Ohio on or before May 1 of each year for rates effective for service r^dered
Filed pursuant to Order dated , in Case No. , before
The Public Utilities Commission of Ohio
Issued by: .President Effective: June 1.2011
The Cleveland Electric Illuminating Company
Cleveland. Ohio P.U.C.O. No. 13
Original Sheet 119
Page1 of 2
RIDER NMB Non-Market-Based Services Rider
APPLICABILITY:
Applicable to any customer who receives electric service under the Company's rate schedules. The Non-Market-Based Services Rider (NMB) charge will apply, by rate schedule, effective for service rendered as described below. This Rider is not avoidable for customers who take electric generation service from a certified supplier.
PURPOSE:
The Non-Markel-Based Services Rider (NMB) will recover non-market-based costs, fees or charges imposed on or charged to the Company by FERC or a regional transmission organization, independent transmission operator, or similar organization approved by FERC including, but not limited toiXii£JM Interconnection. L.L.C, ("PJM") .charges assessed under Schedule 1 fSchgdulino^ System Control ancJ Dispatch Service), Schedule 1A (Transmission Owner Scheduling. System Control and Dispatch Services). Schedule 2 (Reactive Supply and Voltage Control from Generation or Other Sources Services). "Network Integration Transmission Service (NITSV under the PJM Agreements. Schedule 11 (Transitional Market Expansion Charge) and Schedule 12 (Transmission Enhancement Charge) of the PJM Tariff, and fii) Midwest Independent Transmission System Operator. Inc. ("MISO") Jraji5m|ssion Expansion Piao_ (MTEP) charges assessed under Schedule 2S of the MISO. Tar[ff^ whether assessed directly by MISO. PJM or American Transmission Systems. lncorooratedT_
Rider NMB may be updated: 1) to account for changes in existing non-market-based costs, fees or charges^nd,,2}jq^include_an^jion-jTTaj1<et-bas_e^ fees ojchargesjhatwere notvetJn effect£iLthe_ effective date of this Rider and/or"otherwJse Imposed ori or'charged to'the Company by FEl=tC or a regional transmission organization, independent transmission operator, or similar organization approved by FERC.
RATE:
The NMB charge for each rate schedule shall be calculated as follows;
Formatted: Font CDefaulQ Arial, 10 pt
Formatted: Not HighHght
Fonnatted: Font (Default) Arial, 10 pt
Formatted: Font; (Default) Arial, 10 pt
Formatted: Font: (Default) Arial, 10 pt
Formatted: Font: (Default) Arial, ID pt
\ ] Deleted:, Scheduling. System Control and Dispatch Service, Reactive Suppty and Voltage Control Sen/ice and NatworK Integration Transmlsston SoTwfeas.U
Deleted: or n
^A/here:
NMBC
NMB NMBC-E
BU
1
L_I.CATJ
The amount of the Company's total projected Non-Market-Based Services-related costs' for the Computation Period/allocated to each rate schedule.
The Computation Period over which NMB will apply shall be June 1 through May 31 of each year.
Starting June 1,2012, any net over- or under-collection of the Non-MarXel-Based Services-related costs, including applicable interest, invoiced during the period from June 1,2011 to March 31, 2012, allocated to rate schedules. Thereafter, E will be calculated for the 12-month period ending March 31 immediately preceding the Computation Period.
•{ Deleted: -Page Break-
Issued by:
Filed pursuant to Onjer dated , in Case No.
The Public UUIiUes Commission of ONo
' , President
before
Effective; June 1.2011
The Cleveland Electric Illuminating Company
Cleveland, Ohio P.U.C.O. No. 13
Original Sheet 119
Page 2 of 2
RIDER NMB Non-Market-Based Services Rider
BU = Forecasted billing units for the Computation Period for each rate schedule.
CAT = The Commercial Activity Tax rate as established in Section 5751.03 of the Ohio Revised Code.
NMB charges:
RS (allkWhs. perkWh)
GS* (per m of Billing Demand)
GP" (per kW of Billing Demand)
GSU (per kW of Billing Demand)
GT (per kVa of B llling Demand)
STL (all kWhs. per kWh)
TRF (all kWhs, per kWh)
POL {all kWhs. per kWh)
X.)000(^
$x.xxxx $x.xxxx $X.}000i
$x.xxxx
XXXXX0
X.X1OOC0
X.XXXX0
Separately metered outdoor recreation facilities owned by non-profJt^ governmental and educational institutions, such as athletic fields, served under Rate GS or GP, primarily for lighting purposes, viflll be charged per the NMB charge applicable to Rate Schedule POL
RiDER UPDATES:
The charges contained in this Rider shall be updated and reconciled on an annual basis. The Company will file vtfith the PUCO a request for approval of the Rider NMB charges on or before Mav 1 of each year which, shall become effective on a service rendered basis on^une 1_through May 31 pf_the subsequent _ year, unless otherwise ordered by the Commission.
- ' Deleted: Rider NMB wai be filed with tiie Public Utjiftias Commission of QfiB on or betore M^ 1 of sa^ year for rates effecUve for sers^e rendered
Applicable to any customerj-eceiyingrelectric seryice under the Compar^/s rate schedutes except those^ _ __ - - j Delated; \wfto customers served under an existi'nQ special contract thatln'dudes a fixed price for service where such fixed price is different than the rate under the ofhenjtfise applicable tariff and where the contract term includes the period of January 1. 2009 through Way 31. 2009. The following Deferred Generation Cost Recovery Rider (DGC) charges will apply, by rate schedule, effective on a service rendered basis, for all l Whs per l<Wh. This Rider is notavoidableforcustomers who tal<;e electric generation sen/ice from a certified supplier.
1. The amount of this Rider reflects recovery of generation costs deferred from June 2009 through May 2011 due to any future Commission Order plus the associated Commission approved carrying costs on the unrecovered deferred cost balance.
2. The amount of this Rider reflects recovery of generation costs deferred from January 2009 through May 2009 due to Commission Opinion and Order January 14,2009 in Case No. 09-21-EL-ATA plus the associated Commission approved carrying costs on the unrecovered deferred cost balance.
RIDER UPDATES:
The charges contained in this Rider shall be updated and reconciled on an annual basis, or more frequently If necessary, beginning June 1, 2011. The Company will file with the PUCO a request for approval of the Rider charges which, unless otherwise ordered by the PUCO, shall become effective on a service rendered basis on the first day of the subsequent month, but no less than 30 days after the filing of such request.
Filed pursuant to Order dated .'i?P^se_No_ t.
ipeleted: May 27.2009
Deleted: Q8-935^L-SeO et
> \ deleted: Richard R. Grigg
// /(Deleted:2009 D
Issued by: -
J before I
The Public Utilises Commission of Ohio
Pr 5ide_nt _ EfTectiyeiJune^l.^QII *
The Toledo Edison Company
Toledo, Ohio
Sheet 115
P.U.C.O, No. 8 ;]lReyised_Pjge lQf_3.^ ' ^ "Tg Deleted: f
Formatted: Superscript RIDER DSE Demand Side Management and Energy Efficiency Rider
The Company reserves the right to revise such schedule consistent with the Commission's final rules, which may include modification or deletion of ail or portions of this schedule.
APPLICABILITY:
Applicable to any customer that takes electric service under the Company's rate schedules. The following charges will apply, by rate schedule, effective for service rendered beginning J u n e t .2011. for aU kWhs . - 4 Deleted: January perkWh: • " ' ~^ -{ Deleted: 2010
^ y g ^ ^iySQS^ \ ' N t Deleted; ijyooo<0_ _ -x-xxxxj '. ^;,'^i Deleted: 0.0196
I 1 ! , 1 > V '
1:0.0000
i«JS2^_ iy.>go<xji _ ^ * \ ^ t Deleted! 0.0000
The DSE1 charges set forth in this Rider recover costs incumed by the Company associated with customers tai<ing sen/ice under the Economic Load Response Rider (ELR) and Optional Load Response Rider {OLR}.
The DSE2 charges set forth in this Rider recover costs incurred by the Company associated with the programs that may be Implemented by the Company to secure compliance with the, energy efficiency and peak demand reduction requirements In Section 4928.66, Revised Code through demand-response programs, energy efficiency programs, peak demand reduction programs, and self-directed demand-response, energy efficiency or other customer-sited programs. The costs initially deferred by the Company and subsequently fully recovered through this Riderwili be all program costs, including but not limited to any customer incentives or rebates paid, applicable carrying costs, all reasonable administrative costs to conduct such programs, and lost distribution revenues resulting from the implementation of such programs.
*>• .{oateted: 0.0196
\\^\^ t Deleted: 0.0000 V^tOeletedi . o > _ —
0.0196
V 4 Deleted: 0.0000
RIDER UPDATES:
1. The DSE1 charges set forth in this Rider shall be updated semi-annually. No later than December 1st and June 1st of each year, the Company shall file with the PUCO a request for approval of the these charges which, unless otherwise ordered by the PUCO, shall become effective on a service rendered basis on January 1st and July 1st of each year, beoinninQ with theJune 1^011 effectjve date. -/'
,[{ Deleted; 0a-&35-EL-SSO et al.
* / ) Deleted: Rtahard R. Grigg J
Deleted: January
Deleted: 2010 3 Filed pursuant to Order dated, , in Case No.^
The Public Utilities Commission erf Ohio
Issued bv:, . President
i ' f
, before / L\' It!
1l
Effective: j(Juri6.1j^grty
The Toledo Edison Company Original Sheet 115
Toledo, Ohio P.U.C.O. No. 8 Page 2 of 3
RIDER DSE Demand Side Management and Energy Efficiency Rider
2. The DSE2 charges set forth in this Rider shall be updated semi-annually. No later than December 1st and June 1st of each year, the Company shall file with the PUCO a request for approval of the these charges which, unless otheoA/ise ordered by the PUCO, shall become effective on a service rendered basis on January 1st and July 1st of each year, beginning with the January 1, 2010 effective date. The deferred balance at April 30th and at October 31st of each year, utilizing a three year amortization schedule, will be used to calculate the semi-annual charges. This rider shall be in effect until all costs are fully recovered.
AVOIDA8ILITY:
1. The DSE1 charges set forth in this Rider are avoidable only for those customers taking service under Rider ELR and Rider OLR.
2. The DSE2 charges set forth in this Rider are avoidable for Non-Residential customers who (1) are not taking service under either a unique arrangement (special contract) or the Reasonable Arrangements Rider (RAR) and (2) meet the criteria of all of paragraphs a) through e) below.
Each customer applying to the Company to avoid the DSE2 charges must at a minimum meet all of the criteria set forth below and must submit to the Company verifiable infomnation detailing how the criteria are met, and must provide an affidavit from a company official attesting to the accuracy and truthfulness of the information provided. Qualification and verification on an annual basis is required, subject to the Failure to Comply section of this rider.
a) The customer identifies its capital investments and expenses related to customer-sited advanced energy resource programs, alternative energy programs, demand-response programs, energy efficiency programs or peak demand reduction programs.
b) For consideration of avoidance of this Rider, the customer shall provide sufficient data to Illustrate that it has undertaken or will undertake self-directed energy efficiency and/or demand reduction programs that have produced or will produce energy savings and/or peak demand reductions equal to or greater than the statutory benchmarks to which the Company is subject The energy savings and demand reductions resulting from the customer's self-directed programs shall be calculated using the same methodology used to calculate the Company's energy savings and demand reductions for purposes of determining compliance with statutory benchmarks, including normalization adjustments to the baseline, where appropriate.
c) The customer commits, in writing, its customer-sited capabilities for integration into the Company's portfolio of programs such that the customer-sited capabilities shall assist the Company in satisfying the requirements in Section 4928.66, Revised Code.
d) The customer demonstrates to the satisfaction of the Company that the avoidance of the DSE2 charges shall reasonably encourage the customer to commit its customer-sited capabilities for integration into the Company's portfolio of programs described above.
e) The customer commits to use its best efforts to cooperate with and assist the Company in conjunction with any reviews conducted by a regulatory authority of the Company's efforts to utilize the customer's customer-sited capabilities to satisfy the requirements in Section 4928.66, Revised Code.
The customer must complete a standard application form in order to be considered for qualification to avoid charges under this Rider. The Company shall provide a standard application form upon request by the customer. Customers applying to avoid the DSE2 charges must successfully demonstrate that they have completed an energy efficiency project on or after January 1, 2006 without financial support from the Company. The burden of proof to successfully demonstrate compliance with the standard application fonri lies with the customer.
Filed pursuant to Order dated March 25,2009, in Case No. 0B-935-EL-SSO et al., before
The Public Utilities Commission of Ohio
Issued by: Richard R. Grigg, President ' Effective: June 1,2009
The Toledo Edison Company Original Sheet 115
Toledo. Ohio P.U.C.O. No. 8 Page 3 of 3
RIDER DSE Demand Side Management and Energy Efficiency Rider
Upon the Commission's approval of the customer's completed standard application fonn, the DSE2 charges shall be avoidable by the customer as long as, on an annual basis, the customer makes a filing with the Commission demonstrating that it remains eligible for the exemption under the criteria set forth herein.
Customer information provided to demonstrate eligibility under the criteria above shall remain confidential by the Company. Nonetheless, the name and address of customers eligible to avoid the DSE2 charges shall be public infonnation. The Commission Staff shall have access to all customer and electric utility information related to service provided pursuant to the DSE2 charges for periodic and random audits.
REPORTING REQUIREMENTS:
Customers served under this Rider must submit an annual report to the Company (Director, Ohio Rates and Regulatory Affairs), no later than April 30th of each year. The format of that report shall be identical to the Standard Application Form such that a determination of the compliance with the eligibility criteria can bedetennined.
The burden of proof to demonstrate on-going compliance with this Rider lies witii the customer.
CONFIDENTIALITY:
Customer information provided to demonstrate eligibility under this Rider shall remain confidential by the Company. The name and address of customers eligible for the schedules shall be public infonnation. The Public Utilities Commission of Ohio shall have access to all customer and Company information related to service provided pursuant to this Rider for periodic and random audits.
FAILURE TO COMPLY:
If the customer being provided with service pursuant to this Rider fails to comply with any of the criteria for eligibility to avoid charges under this Rider, the Company will provide reasonable notice to the customer that the customer will pay all charges under this Rider. Furthermore, the Company shall charge the customer for the sum of all of the customer's avoided charges realized under this Rider, which the customer shall thus be obligated to pay.
Filed pursuant to Order dated March 25,2009, in Case No. 08-935-EL-SSO et al., before
The Public Utilities Commission of Ohio
Issued by: Richard R. Grigg, President ' Effective: June 1,2009
Ohio Edison Company
I Akron, Ohio P.U.C.O. No. 11
Sheet 115
1 ^ Aeyisej_P_age 1_ of _3_ - - { Deletedr-T
i Formatted: Superscript RIDER DSE
Demand Side Management a n d Energy Ef f i c iencv Rider
The Company reserves the right to revise such schedule consistent with the Commission's final nj ies, which may Include modification or deletion of all or portions of this schedule.
APPLICABILITY:
Applicable to any customer that takes electric service under the Company's rate schedules. The following ^ — ^ charges wiil apply, by rate schedule, effective for service rendered beginning J u n e t j Q _ 1 1 . for alUVVhs „ - -[Deleted: January pe rkWh : ' " - - - 1 ^ , ^ ' . „ ^ „
1 Paletcd: 201Q
RATE: DSE1 DSE2
RS
GS
GP
GSU
GT
STL
TRF
POL
PROVISIONS:
, J 0 ^ 2 S ^ ^ ^ - - ' iPg 'e ted : 0.0196
.^ ( jX^y i ^ .xxxx^ ~ ' "[Deleted: 0.0000
^ y ^ « S t _ •^•>G00{^ ^ " " V 1 Deleted; 0.0196
igcoo<^_ _ ^ j(.xxxxj i '^\.^'(Deleted:0.000Q
^ggq<Xjt ^ y S £ £ ^ '^^^\' '| Deleted; 0.0196
^jOM<si_ _ ^.xxxxffc -;vv4 Deleted: O.DOOO
0.0196 , <-.>QOfXA ^^xxxxj^ i;;,v I Deleted;
^>gxxgi . ^ g ^ g g l . , \ \ \ \ ""1 Deleted: 0.0000
Deleted: 0.0196
The DSE1 charges set forth in this Rider recover costs incurred by the Company associated with customers taking service under the Economic Load Response Rider (ELR) and Optional Load Response Rider (OLR).
The DSE2 charges set forth in this Rider recover costs Incuned by the Company associated with the programs that may be implemented by the Company to secure compliance Vfltii the, energy efficiency and peak demand reduction requirements in Section 4928.66. Revised Code through demand-response programs, energy efficiency programs, peak demand reduction programs, and self-directed demand-response, energy efficiency or other customer-sited programs. The costs initially deferred by the Company and subsequently fully recovered through this Rider will be all program costs, including but not limited to any customer incentives or rebates paid, applicable carrying costs, all reasonable administrative costs to conduct such programs, and lost distribution revenues resulting from the implementation of such programs.
ji'^'^t Deleted: Q.DD0D
tt M Deleted: 0.0196
Deleted: O.OtKK}
Deleted: 0.019S
Deleted: 0.0000
Deleted: 0.0196
{Deleted; D.QOK)
RIDER UPDATES:
The DSE1 charges set forth in this Rider shall be updated semi-annually. No later than December 1st and June 1st of each year, the Company shall file with the PUCO a request for approval of the these charges which, unless otherwise orelered by the PUCO, shall become effective on a service rendered basis on January 1st and July 1st of each year, beginning with theJune 1,^011 effect[ve date.
Filed pursuant to Order dated. in Case No., before
RIDER DSE Demand Side Management and Energy Efficiencv Rider
2. The DSE2 charges set forth in this Rider shall be updated semi-annually. No later than December 1st and June 1st of each year, the Company shall file with the PUCO a request for approval of the these charges which, unless otherwise ordered by the PUCO, shall become effective on a service rendered basis on January 1st and July 1st of each year, beginning with the January 1. 2010 effective date. The deferred balance at April 30th and at October 31st of each year, utilizing a three year amortization schedule, will be used to calculate the semi-annual charges. This rider shall be in effect until all costs are fully recovered.
AVOID ABILITY:
1. The DSE1 charges set forth in this Rider are avoidable only for those customers taking service under Rider ELR and Rider OLR.
2. The DSE2 charges set forth in this Rider are avoidable for Non-Residential customers who (1) are not taking service under either a unique arrangement (special contract) or the Reasonable Arrangements Rider (RAR) and (2) meet the criteria of ail of paragraphs a) through e) below.
Each customer applying to the Company to avoid the DSE2 charges must at a minimum meet all of the criteria set forth below and must submit to the Company verifiable infonnation detailing how the criteria are met. and must provide an affidavit from a company official attesting to the accuracy and truthfulness of the information provided. Qualification and verification on an annual basis is required, subject to the Failure to Comply section of this rider.
a) The customer identifies its capital investments and expenses related to customer-sited advanced energy resource programs, alternative energy programs, demand-response programs, energy efficiency programs or peak demand reduction programs.
b) For consideration of avoidance of this Rider, the customer shall provide suffident data to illustrate that it has undertaken or will undertake self-directed energy efficiency and/or demand reduction programs that have produced or will praduce energy savings and/or peak demand reductions equal to or greater than the statutory benchmarks to which the Company is subject The energy savings and demand reductions resulting from the customer's self-directed programs shall be calculated using the same methodology used to calculate the Company's energy savings and demand reductions for purposes of determining compliance with statutory benciimarks, including normalization adjustments to the baseline, where appropriate
c) The customer commits, in writing, its customer-sited capabilities for integration into the Company's portfolio of programs such that the customer-sited capabilities shall assist the Company in satisfying the requirements in Section 4928.66, Revised Code.
d) The customer demonstrates to the satisfaction of the Company that the avoidance of the DSE2 charges shall reasonably encourage the customer to commit its customer-sited capabilities for integration into the Company's portfolio of programs described above.
e) The customer commits to use its best efforts to cooperate with and assist the Company in conjunction with any reviews conducted by a regulatory authority of the Company's efforts to utilize the customer's customer-sited capabilities to satisfy the requirements in Section 4928.56, Revised Code.
The customer must complete a standard application form in order to be considered for qualification to avoid charges under this Rider. The Company shall provide a standard application form upon request by the customer. Customers applying to avoid the DSE2 charges must successfully demonstrate that they have completed an energy efficiency project on or after January 1, 2006 without financial support from the Company. The burden of proof to successfully demonstrate compliance with the standard application form lies with the customer.
Filed pursuant to Order dated March 25,2009, in Case No. 08-935-EL-SSO et al.. before
The Public Utilities Commission of Ohio
Issued by: Riclnard R. Grigg, President Effective: June 1, 2009
Ohio Edison Company Original Sheet 115
Akron. Ohio P.U.C.O. No. 11 Page 3 of 3
RIDER DSE Demand Side Management and Energy Efficiency Rider
Upon the Commission's approval of the customer's completed standard application form, the DSE2 charges shall be avoidable by the customer as long as, on an annual basis, the customer makes a filing with the Commission demonstrating that it remains eligible for the exemption under the criteria set forth herein.
Customer information provided to demonstrate eligibility under the criteria above shall remain confidential by the Company. Nonetheless, the name and address of customers eligible to avoid ., the DSE2 charges shall be public information. The Commission Staff shall have access to all customer and electric utility information related to service provided pursuant to the DSE2 charges for periodic and random audits.
REPORTING REQUIREMENTS:
Customers served under this Rider must submit an annual report to the Company (Director, Ohio Rates and Regulatory Affairs), no later than April 30th of each year. The format of that report shall be identical to the Standard Application Form such that a determination of the compliance with the eligibility criteria can be determined.
The burden of proof to demonstrate on-going compliance with this Rider lies with the customer,
CONFIDENTIALITY:
Customer information provided to demonstrate eligibility under this Rider shall remain confidential by the Company. The name and address of customers eligible for the schedules shall be public information. The Public Utilities Commission of Ohio shall have access to all customer and Company information related to service provided pursuant to this Rider for periodic and random audits.
FAILURE TO COMPLY:
If the customer being provided with service pursuant to this Rider fails to comply with any of the criteria for eligibility to avoid charges under this Rider, the Company will provide reasonable notice to the customer that the customer will pay all charges under this Rider. Furthenmore, the Company shall charge the customer for the sum of all of the customer's avoided charges realized under this Rider, which the customer shall thus be obligated to pay.
Filed pursuant to Order dated March 25, 2009, in Case No. 08-935-EL-SSO et al., before
The Public Utilities Commission of Ohio
Issued by: Richard R. Grigg, President ' Effective: June 1,2009
The Cleveland Electric Illuminating Company
Cleveland, Ohio P.U.C.O. No. 13
Sheet 115
^R_eyise_d_P_age_1_of 3_^ - - -(Deleted: 1'
RIDER DSE Demand Side Management and Energy Efficiencv Rider
The Company reserves the right to revise such schedule consistent with the Commission's final rules, which may include modification or deletion of all or portions of this schedule.
APPLICABILITY:
Applicable to any customer that takes electric service under the Company's rate schedules. The following charges will apply, by rate schedule, effective for service rendered beainnino June 1.^011. for all kWhs perkWh: - - ' " '
Formatted: Superscript
- - -(Deleted: January
i Deleted: 2010
RATE: DSE1 DSE2
RS
GS
GP
GSU
GT
STL
TRF
POL
PROVISIONS
1
^ < j » ^ . ;<J^9^.
TJ JB' -LJI MM U ^ , B « V ^ _ — - ^ • > ' ^ — - H — — — .»j 111 nil III (4 ^
The DSE1 charges set forth in this Rider recover costs incurred by the Company associated with customers taking service under the Economic Load Response Rider (ELR) and Optional Load Response Rider (OLR).
The DSE2 charges set forth in this Rider recover costs incumed by the Company associated with the programs that may be implemented by the Company to secure compliance with the, energy efficiency and peak demand reduction requirements in Section 4928.65, Revised Code through demand-response programs, energy efficiency programs, peak demand reduction programs, and self-directed demand-response, energy efficiency or other customer-sited programs. The costs initially deferred by the Company and subsequently fully recovered through this Rider will be all program costs, including but not limited to any customer incentives or rebates paid, applicable carrying costs, all reasonable administrative costs to conduct such programs, and lost distribution revenues resulting from the implementation of such programs.
RIDER UPDATES:
1. The DSE1 charges set forth In this Rider shall be updated semi-annually. No later than December 1st and June 1st of each year, the Company shall file with the PUCO a request for approval of the these charges which, unless otherwise ordered by the PUCO, shall become effective on a service rendered basis on January 1st and July 1st of each year, beginning with the June_1,2011 effective date.
Filed pursuant to Order dated.
Issued by:
i.iri Case_No^
The Public Utilities Commission of Ohio
Pr_eside_nt * Effective: yJune 1 2011 /
The Cleveland Electric Illuminating Company Original Sheet 115
Cleveland, Ohio P.U.C.O. Mo. 13 Page 2 of 3
RIDER DSE Demand Side Management and Energy Efficiencv Rider
2. The DSE2 charges set forth in this Rider shall be updated semi-annually. No later than December 1st and June 1st of each year, the Company shall file with the PUCO a request for approval of the these charges which, unless otherwise ordered by the PUCO, shall become effective on a service rendered basis on January 1st and July 1st of each year, beginning with the January 1, 2010 effective date. The deferred balance at April 30th and at October 31st of each year, utilizing a three year amortization schedule, will be used to calculate the semi-annual charges. This rider shall be in effect until all costs are fully recovered.
AVOIDABILITY:
1. The DSE1 charges set forth in this Rider are avoidable only for those customers taking service under Rider ELR and Rider OLR.
2. The DSE2 charges set forth in this Rider are avoidable for Non-Residential customers who (1) are not taking service under either a unique arrangement {special contract) or the Reasonable Amangements Rider (IRAR) and (2) meet the criteria of all of paragraphs a) through e) below.
Each customer applying to the Company to avoid the DSE2 charges must at a minimum meet all of the criteria set forth below and must submit to the Company verifiable information detailing how the aiteria are met, and must provide an affidavit from a company offida) attesting to the accuracy and truthfulness of the infonnation provided. Qualification and verification on an annual basis is required. subject to the Failure to Comply section of this rider
a) The customer identifies its capital investments and expenses related to customer-sited advanced energy resource programs, alternative energy programs, demand-response programs, energy efficiency programs or peak demand reduction programs.
b) For consideration of avoidance of this Rider, the customer shall provide sufficient data to illustrate that it has undertaken or will undertake self-directed energy efficiency and/or demand reduction programs that have produced or will produce energy savings and/or peak demand reductions equal to or greater than the statutory benchmarks to which the Company is subject The energy savings and demand reductions resulting from the customer's self-directed programs shall be calculated using the same methodology used to calculate the Company's energy savings and demand reductions for purposes of detemiining compliance with statutory benchmarks, including nonnalization adjustments to the baseline, where appropriate.
c) The customer commits, in writing, its customer-sited capabilities for integration into the Company's portfolio of programs such that the customer-sited capabilities shall assist the Company in satisfying the requirements in Section 4928.66. Revised Code.
d) The customer demonstrates to the satisfaction of the Company that the avoidance of the DSE2 charges shall reasonably encourage the customer to commit its customer-sited capabilities for integration into the Company's portfolio of programs described above.
e) The customer commits to use its best efforts to cooperate with and assist the Company in conjunction with any reviews conducted by a regulatory authority of the Company's efforts to utilize the customer's customer-sited capabilities to satisfy the requirements In Section 4928.66, Revised Code.
The customer must complete a standarci application form in order to be considered for qualification to avoid charges under this Rider. The Company shall provide a standard application form upon request by the customer. Customers applying to avoid the DSE2 charges must successfully demonstrate that they have completed an energy efficiency project on or after January 1, 2006 without financial support from the Company. The burden of proof to successfully demonstrate compliance with the standard application form lies with the customer.
Filed pursuant to Order dated March 25, 2009, in Case No. oa-935-EL-SSO el al., before ~~~
The Public Utilities Commission of Ohio
Issued by: Richard R. Grigg, President ' Effective: June 1, 2009
The Cleveland Electric Illuminating Company Original Sheet 115
Cleveland, Ohio P.U.C.O. No. 13 Page 3 of 3
RIDER DSE Demand Side Management and Energy Efficiency Rider
Upon the Commission's approval of the customer's completed standard application form, the DSE2 charges shall be avoidabte by the customer as long as, on an annual basis, the customer makes a filing with the Commission demonstrating that it remains eligible for the exemption under the criteria set forth herein.
Customer information provided to demonstrate eligibility under the criteria above shall remain confidential by the Company. Nonetheless, the name and address of customers eligible to avoid the DSE2 charges shall be public information. The Commission Staff shall have access to alt customer and electric utility information related to service provided pursuant to the DSE2 charges for periodic and random audits.
REPORTING REQUIREMENTS:
Customers served under this Rider must submit an annual report to the Company (Director, Ohio Rates and Regulatory Affairs), no later than April 30th of each year. The format of that report shall be identical to the Standard Application Form such that a determination of the compliance with the eligibility criteria can be determined.
The burden of proof to demonstrate on-going compliance with this Rider lies with the customer.
CONFIDENTIALITY:
Customer information provided to demonstrate eligibility under this Rider shall remain confidential by the Company. The name and address of customers eligible for the schedules shall be public infonnation. The Public Utilities Commission of Ohio shall have access to all customer and Company infonnation related to service provided pursuant to this Rider for periodic and random audits.
FAILURE TO COMPLY:
If the customer being provided viflth service pursuant to this Rider fails to comply with any of the criteria for eligibility to avoid charges under this Rider, the Company will provide reasonable notice to the customer that the customer will pay ail charges under this Rider. Furthemiore, the Company shall charge the customer for the sum of all of the customer's avoided charges realized under this Rider, which the customer shall thus be obligated to pay.
Filed pursuant to Order dated March 25, 2009, in Case No. 0&-935-EL-SSO et al.. before
The Public Utilities Commission of Ohio
Issued by: Richard R. Grigg, President ' Effective: June 1,2009
The Toledo Edison Company
Toledo, Ohio P.U.C.O. No. 8
Sheet 114
^ AQyigsJ-PggQ, 1 Qf j - - -
RIDER GEN Generation Service Rider
APPLICABILITY:
For customers taking the Standard Service Offer electric generation service fSSO Generation Service") from the Company, the following Standard Service Offer Generation Charges (SSOGC) by rate schedule, . vAW apply, effective for service rendered beginning Jun^ 1. 2011, for all kWhs per kWh. unless otherwise .—--{ Deleted: F»bmary...o noted: nM Capacity costs resulting from annual PJM auctions (including the PJM-administered Fixed Resource Requirement, auctigns conducted in March 2010^_wil[ be' caltulated by Company and by tariff schedule based on the average of coincident peaks, induding distribution losses, for the months of June through September of the year prior to the year in which the auction occurred. The calculated wholesale capacity costs are used to develop capacity charoes.
-[ Deleted: RR
These calculated wholesale capacity costs will be converted to an energy basis and will then be subtracted from the SSP CBP results to develop the non-capacity related energy charges.
RATE:
Caoacitv Charoes RS GS GP GSU GT STL TRF POL
Summer X.XXXX(i
x.xxxxi X.XXXX^
x.xxxxai X.XXXXfli
X.XXXXtt
X.XXXX*
x.xxxx(i
Winter xxxxxii x.xxxxi x.xxxxi X.XXXXfli
x.xxxx(i x.xxxxii X.XXXX^
x-xxxxd
Energy Charoes
m . ^ S GP GSU GT STL TRF POL
Summer
Jii2S2!^ J S E ^ O C C ^
^ x > q o ^
>Se>2?>£Sl.
2 i 3 0 ? ^ X f i o o ^
2t^>Sl
Filed pursuant to Order dated^ j.ini;ase_No^,
Winter
J t i 2 2 ^ x.xxxxi
) xxxxifc •^xxx;^ X-XXXX^
before
Formatted: Font Not Bold, No underline
-'-u "".i Fonnatted: Space After; 3 pt
Deleted; H
~ i Formatted: Indent U f t 0,25"
Deleted: H Firat 500 ICVWTS, per kWh
Deleted: 6...8818...6...3047
Deleted: All excess kWhs, per kWh. 7.88180.6.3047^ir
m
5.,.9143
.SOBSr
Deleted: 7...3563...B...3047 C ^ m .
Deleted: 7...3568...6...3047 r r g
Deleted: 7...3568...6...3047
De f i ed : January 20.2010...(S-541 EL-ATA flOlJ
Deleted: Richard R. Grigg...FebmaTy ...2010 j ,,, m i
Issued by:.
The Public Utilities Commission of Ohio / -> f f?side_nt Effective; June 1 .. 011 /
For customers with the appropriate qualifying time-of-day metering and who elect to be served under the Time-Of-Day Option, the charge by rate schedule will be as shown below, for all kWhs, per l<Wh:
Caoadb/ Charaes
GS GP GSU GT
Midday Peak
x.xxxx<i x.xxxx(i x.xxxx(i x.xxxxi
Summer Shouider
Peak
x.xxxxrf x.xxxxd x.xxxx(i x.xxxxi
Off-Peak
X.XXXX(i
x.xxxx(i x.xxxx«i x.xxxxi
Middav Peak
x.xxxxi x-xxxxi x.xxxxi X.XXXX0
Winter Shoulder
Peak
x.xxxxi x.xxxx^ x.xxxxi x.xxxxii
Off-Peak
X.XXXXtS
x-xxxxi x.xxxxii x.xxxx?S
Energy Charaes
GS
GP
Summer Winter. Midday Peak
Shoulder Peak Off-Peak
Midday Peak
XXt)OCX>9i_ _ _ ] ^ , ^ ^ ^ ^ . - X j Q O y j ^ jtjO(XX(^
Midday-peak time shall be noon to 6 p.m. EST, Monday through Friday, excluding holidays.
Shoulder-peal< time shall be 6:00 a.m. to noon and 6 p.m. to 10 p.m. EST, Monday through Friday, excluding holidays.
Holidays are defined as New Year's Day, Memorial Day, Independence Day, Labor Day, Thanksgiving Day, and Christmas Day. Off-Peak shall be all other hours.
A customer may terminate its participation in this time-of-day option at any time effective with the next scheduled meter reading. A qualifying customer may return to the time-of-day option at any time after a hiatus from the time-of-day option of at least one (1) year.
METERING:
The customer must arrange for time-of-day metering consistent with the Company's Miscellaneous Charges, Tariff Sheet 75.
Deleted: 4.8133 . 7.2960 . 8.3453 ^.4.4780*11 GSU
i ,4 0
Deleted: 12
Deleted: 18QG
Deleted: 7
Deleted: 7318
Deleted: 4.6780 . 7.0910 .8.1107 ^.4.3521 #^ GT
J
Deleted: 12
Deleted: 1684
Deleted: 7
7241
Deleted: 4.673391.7.0839 . 8.1026 ^ 4.3478^
Deleted: January 20,2010
Deleted: 09-541-EL-ATA
Deleted: Richard R. Grigg
Deleted: Fabiuary
Deleted: 2010 Filed pursuant to Order dated^ j_inCase_No^^ before I ' F f
Issued by;
The Public Utilities Commission of Ohio */'
Pr_eside_nt _ Effectiye: June i.2011 /
Ohio Edison Company
Akron, Ohio P.U.C.O. No. 11
Sheet 114
f Revised Page 1 of 2
RIDER GEN Generation Service Rider
APPLICABILITY:
For customers taking the Standard Service Offer electric generation service ("SSO Generation Service") from the Company, the following Standard Service Offer Generation Charges (SSOGC) by rate schedule,
I will apply, effective for service rendered beginning June, I^.^OH fqr_ail kWhs per^kWh, iJnless_otherwise _ noted:
'{Deleted: Febmery
-f Deleted: 2010
Caoacitv costs resulting from annual PJM auctions fincludino the PJM-administered Fixed Resource ,, Reauirement^uctions conducted iri March 201 Oywill be calculated by Qpnipany and by tariff schedule _ - - { Deleted: RR based on the average of coincident peaks, including distribution losses, for the months of June through September of the j/ear prior to tiie year in <yhich tiie auction occurred. Thecalculated wholesale capacity _ - 4 Deleted: prior costs are used to develop capacity charaes.
These calculated wholesale capacity costs will be converted to an energy basis and.will then be subtracted from the SSO CBP results to develop the non-caoadW related energy charges.
Deleted: 6.8818 . 6.30470 Deleted: All excess kWhs, per kWh. 7.8818^6.3047011
^ ' Deleted: 7.356S0.6.30470
Deleted: 7.10140.6.0659011
Deleted! 6.90170.5.9148011
Deleted: 6.89480.5.9085011
Deleted: 7.35B80.6.3O470H
Deleted: 7.35660
•iOfXXrf, - ' " " - " — - - - f S ^ e d : 6.30470
-f Deleted: 7.35680.6.30470
Filed pursuant to Order dated^ inCase^ No^
Issued t3y: ^
The Public Utilities Commission of Ohio
Prestdejit EfTective: June 1.^011 /
Ohio Edison Company
Akron, Ohio P.U.C.O. No. 11
Original Sheet 114
Page 2 of 2
RIDER GEN Generation Service Rider
TIME.OF-DAY OPTION:
For customers with the appropriate qualifying time-of-day metering and who elect to be served under the Time-Of-Day Option, the charge by rate schedule will be as shown below, for all kWhs, per kWhi
Caoacitv Charaes
GS
GP
GSU GT
Middav Peak
x.xxxxii
x.xxxxi
x.xxxxi
x.xxxxi
Summer Stiaulder
Peak
x.xxxxi
x.xxxxii
x.xxxxtf
x.xxxxi
Off-Peak
x.xxxxi
x.xxxxi
x.xxxxii
x.xxxx(i
Middav Peak
X.XXXX(i
X.xxxx*
x.xxxxii
X.XXXX(i
Winter Shoulder
Peak
x.xxxxi
x.xxxxi
x.xxxxi
x.xxxx(i
Off-Peak
x.xxxxii
x.xxxxtf
x.xxxx^
x.xxxxi
Enerov^ Charaes
GS
GP
GSU GT
Midday Peak
x.xxxxtf
x.xxxxi
x.xxxxii
x.xxxxti
Summer Shoulder
Peak
x.xxxxii
X.XXXXEi
x.xxxxii
x.xxxxii
Off-Peak
x.xxxxtf
X.XXXX(i
x.xxxx^
x.xxxxd
Midday £eik
x.xxxxtf
x.xxxxd
x-xxxxd
x-xxxxi
Winter Shoulder
Pea
X-XXXXi
x.xxxx^
x.xxxxi
X.XXXX(i
• -
Off-Peak
X.XXXXQi(
x.xxxxi,
X.XXXX^
x.xxxxfi
~[ Formatted; Indent: Leffa 0.13" j
^ Formatted: Font: Italic, Underline |
Midday-peal^timeshalTbe noon'to 6 p.m. EST^ Monday'througTi Friday, excludlri g holidays.
Shoulder-peak time shall be 6:00 a.m. to noon and 6 p.m. to 10 p.m. EST, Monday through Friday, excluding holidays.
Holidays are defined as New Year's Day, Memorial Day, Independence Day, Labor Day, Thanksgiving Day, and Christmas Day. Off-Peak shall be all other hours.
A customer may terminate its participation in this time-of-day option at any time effective with the next scheduled meter reading. A qualifying customer may return to the time-of-day option at any time after a hiatus from the time-of-day option of at least one (1) year.
METERING:
The customer must arrange for time-of-day metering consistent with the Company's Miscellaneous Charges, Tariff Sheet 75.
Filed pursuant to Order dated. in Case No.^ before
Issued by:
The Public UtiJilies Commission of Ohio
PresidejTt " Effective: June 1.^011
X Deleted
'^{Deleted
: January 20,2010 j
: 09-541-EL-ATA ]
Deleted: Richard R. Grigg
Deleted: February
Deleted: 2010
The Cleveland Electric Illuminating Company
Cleveland, Ohio P.U.C.O. No. 13
Sheet 114
2 ^ Revised Page1of2 ,
RIDER GEN Generat ion Serv ice Rider
- - [ Deleted; 1"
"" 1 Formatted: Superscript
APPLICABIL ITY:
For customers tal<ing the Standard Service Offer electric generation service C'SSO Generation Service") from the Company, the following Standard Service Offer Generation Charges (SSOGC) by rate schedule, will apply, effective for service rendered beginning J u n e ^ l ^ 0 1 1 ^ fqr_ail kWhs per_kWhj unIess_otlierwise_ __ , - -[ Deleted: Februaty noted: ~ " " ~~ ~" ^ Deleted; 0
Capacity costs resulting from annual PJM auctions fincludino the PJM-administered Fixed Resource Requirement auctions conducted in March 2010) will be calculated bv Company and bv tariff schedule based on the average of coincident peaks, including distribution losses, for the months of June through September of the year prior to the year in which the auction occurred. The calculated wholesale capaciW costs are used to develop capacity charges.
These calculated wholesale capacity costs will be converted to an energy basis and will then be subtracted from the SSO CBP results to develop the non-capacity related energy charges.
[ Formatted: Tabs: Not at 3" + 6" J
RATE: Formatted: Font: Not Bold, No UFKlerline
Caoacity Charaes
RS
GS
GP
GSU
GT
STL
TRF
POL
Summer
x.xxxxi
x.xxxxii
x.xxxxi
x.xxxxti
x.xxxxti
x.xxxxii
x.xxxxtf
x.xxxxrf
Winter
x.xxxxi
x.xxxx<i
x.xxxxd
x.xxxxii
x.xxxxrf
x.xxxxii
x.xxxxtf
x.xxxx(2
Energy Charaes
^ § , _
Summer
XJOOX^
Winter JO00C<^
p S XXXXX<f
GP x.xxxxd
j o o a x ^
x.xxxxi^
p S U x^xxxxji
GT x.xxxxi^
STL x.xxxx^
j o o o c < d ^ _
x .xxxx^
x.xxxx^
J R F , XJQKXtf
POL x.xxxxi^
j c ^ g < ^
Formatted: Space After: 3 pt
Deleted; H
Deleted: H FirstSOOkWhs, perkWh
Deleted: 6.88180. B.3O470
Deleted: All excess kV^nis, per kVWi-7.B8ie0.6.30470^
Deleted: 7.35680.6.30470
Deleted: 7.10140.6.0859011
x.xxxx^ " ^ Deleted: 7.35680.6.30470?^
Deleted: 7.35680.6.3047011 11 II Deleted: January 20,2010
Deleted: February
/' /,' \ Deleted: 2010
Filed pursuant lo Order dated, in Case No. before
Issued by:
The Public Utilities Commission of Ohio
President
- / "/ J >u
H I
1
Effective: .mxj
The Cleveland Electric Illuminating Company
Cleveland, Ohio
.- -| Deleted: Original
P.U.C.O. No. 13
^heet.1_14_
'li'AsyigedPgge.i.Q^J, ~ - ' i Formatted: Superscript
RIDER GEN Generation Service Rider
TIME-OF-DAY OPTION:
For customers with the appropriate qualifying time-of-day metering and who elect to be served under the Time-Of-Day Option, the charge by rate schedule will be as shown below, for all kWhs, per kWh:
Holidays are defined as New Year's Day, Memorial Day, Independence Day, Labor Day, Thanksgiving Day, and Christmas Day. Off-Peak shall be all other hours.
A customer may terminate its participation in this time-of-day option at any time effective with the next scheduled meter reading. A qualifying customer may return to the time-of-day option at any time after a hiatus from the time-of-day option of at least one (1) year.
METERING:
The customer must arrange for time-of-day metering consistent with the Company's Miscellaneous Charges, Tariff Sheet 75.
RIDER AM! Advanced Meteririqlnfrastructure / Modern Grid Rider
APPLICABILITY:
Applicable to any customer who receives electric service under the Company's^te^ch_edLiIes._The Advanced Metering Infrastructure / Modem Grid charge ("AMI Charge") will apply'for all;rata^hedutes^ ~_ _ exciusive of customers who take service under Rate GT. for all kWhs per kWh. This Rider is not avoidable for customers who take electric generation service from a certified supplier.
RATE:
I AMI Charge 0.0000^
RIDER UPDATES:
The charge contained in this Rider shall be updated and reconciled on quarter ly basJ5_. Npjater_than_ December 1st. March 1st. June 1st and September 1stj)f each^earj^ t_hepprnpan^^shall file_with theT _ PUCO a request for approval of the rider charges which, unless othenwfee ordereli b'y the PUCO, shall „ , become effective on a service rendered basis on January 1st April 1st July 1st and October 1st of.gach_ _ " j Deleted; November t
- - •{ Deleted: R
~- -j Deleted: S 1 1
\ ^ i Deleted: R )
\ Deleted: S j
'* ---(Deleted! perkWh 1
- - -( Delated: n
"•-(Deleted: annual 1 1
year, _ _ _ ~ ~ ' ~ *{ Deleted: the fbltowftig
1 Deleted:. begmnftug wfth October 1, 2011.
Dieted: January 21,2009
Deleted: 07-551-EL-AIR
Deleted: Rictiard R. Grigg
Filed pursuant lo Order dated, , in Case No., . before / *,v ^
The Public Utilities Commission of Ohio ^ Issued by: ^_ __^ PresidejiL EfTective: June 1^2011 /
Deleted: January I
V :^!|P«'eted:23
/ i!?(Pe'eted!2009 )
Ohio Edison Company ^heet 106 , - - { Deleted; Original
RIDER AMI Advanced Metering Infrastructure / Modern Grid Rider
APPLICABILITY:
Applicable to any customer who receives electric service under the Company's^ateschedules. The _ - -f Deleted: R Advanced Metering Infrastructure / Modern Grid charge ("AMI Charge") will apply for alf^teicl ledyres^ - - ^ ^ j " ^ exclusive of customers who take service under Rate GT. for all kWhs per kWh. This Riderls not ~ " ~ ^ ^ - ^ avoidable for customers who take electric oeneration service from a certified supplier. \ T Deleted; R
Deleted: S
RATE:
AMI Charge O.DOGO i. - -{Deleted: perkwiT
RIDERUPDATES:
The charge contained in this Rider shall be updated and reconciled on a^uarterly basis. No later than_ _ _ - 4 Deleted: n J December 1st March 1st. June 1st and September 1st of ea_ch jear, the Company_shaii fite with th~e ^'~_ ' - - j .. , ! PUCO a request for approval of the rider charaes which" unless othprwise nrrisnaH hv'm« P l l r in shall ' ~" - , | peietea. annu ) PUCO a request for approval of the rider charges which, unless othe~n/vlsi ordered by'the PUCO, s'hall - ^ j become effective on a service rendered basis on Januan^ 1st April 1st July 1st and October Ist of^gdi^ j Deleted: November i | y^3''a ^'"•~ ^ Deleted: the following ]
I V " ** Deleted;, beginning with October 1, 2011.11
Formatted; Font: (Default) Arl^, 10 pt
Filed pursuant to Order dated, in Case_No , ^ before
The Public Utilities Commission of Ohio
Issued by: ^ _ _ ^ PLSsident _ Effective: June"
The Cleveland Electric Illuminating Company
Cleveland, Ohio
- " 1 D^*^^^' Of^'"^'
P.U.C.O. No. 13
^She_etlOS.
l f _R_sy'gs_d_Pjg% 1 °U - - - ' •{ Formatted: Superscript
RIDER AMI Advanced Metering Infrastructure / Modern Grid Rider
APPLICABILITY:
Applicable to any customer who receives electric service under the Company's j:ate^ch_edu!es._Th_e_ _ Advanced Metering Infrastructure / Modern Grid charge ("AMI Charge") will apply for alfjiate^hadutes^ exciusive of customers who take service under Rate GT. for ail kWhs per kWh. This Rider is not avoidable for customers who take electric generation service from a certified supplier.
RATE:
I AMI Charge 0.0000?^_
Deleted: R
Deleted: S
Deleted: R
Deleted: S
, - - -[ Deleted: per kWh
RIDER UPDATES:
The charge contained in this Rider shail be updated and reconciled on ^uarter lY basjs^ ^^ojaterjhan December 1st March 1st June 1st and September Ist j i f e^ch^ear^tj^epompanyshalj file with the ~ PUCO a request for approval of the rider charges which, unless othenwise onjered by "the PUCO, shall become effective on a service rendered basis on January 1st April 1st July 1st, and October 1st of .each year, ,__ r
Deleted: n
Deleted: annual
Deleted; November 1
Deleted:" 1
Formatted: Superscript
Deleted: the following
Deleted:, beginning wUh October 1. 2011.11
, in Case No._ before
( Deleted: January 21, 2009
i\{ Deleted;
//{•Deleted:' 07-551-EL-AIR 3 Richard R. Srigg
'/ ' { Deleted: May
\ Deleted: 2009
Issued by: ^
Filed pursuant to Order dated.t_
TTie Public Utilities Commission of Ohio
, Presjdejit Effecave: jJune,1j^011.y
If 1 /
• I " i
J 'h
The Toledo Edison Company
Toledo, Ohio P.U.C.O. No. 8
Sheet 103
.^Revised Page 1. of 2
RIDER GCR Generation Cost Reconciliation Rider
APPLICABILITY:
DefetedrS"*
{ Formatted: Superscript r)
Applicable to any customer who receives electric service under the Company's rate schedules. The Generation Cost Reconciliation Rider (GCR) charge>wil apply, r a t e schedule effective for service rendered beginning Jijne, 1, a o i j , for al! kWhs per kVVhv
RATE:
J^S. GS. STL. TRF, FCL
GP
GSU
GT
GCR1
_.-..^-xxxxj^
X-XXXXi
x.xxxxii
x.xxxxi
GCR2
x.xxxxii
X.XXXXC
X.XXXX2
X.XXXXjJ
The GCR charge ;shall be calculated as follows:
GCR = (LGCR Deferral Saiancel / ST x 1/(1 - CAT) x ( d - LOSSawr,') / (1 - LQSS^V
Where:
i The calculation period is the three-month period ended two months prior to the effective dates of the updated rider (i.e. three months ended October 31. January 31, April 30, and July 31).
ii. Each cc-mccnent ct the formula includes the aaorecated data for The Cleveland £;ectric lllijminatipQ Comcany Ohio Edison Company, and The Toledo Edison Company.
iii. For any Given biliing oeriod. only the non-zero GCR charge will be acpiied.
Peteted;/(credit)
Deieied:fbr^
Deleted: February
^Ddcted:Q
Ddtfed; This Rider b not avold^Me 1 for oustomecs who taite elecbtc generation setvice from a certified
[ sup|;riter ^ ^
FPimatted: Tabs: 4.5", Centered-f 5.63", Centered
Fcomattod: Space Mter: 3pt,Tabs: 4.5", Gsntered + 5.63", Cencered + Not at 5.5"
The actuai nsconciliation balance, including applicable interest, at the end of the previous calculation period.
The actual revenue associated with Rider GCR, as billed for the calculation period, excluding applicable Commercial Activity Tax.
The actua! revenue associated with Riders GEN, RTP and CPP as l;>illed for the calculation period, excluding applicable Commercial Activity Tax.
The actual cost of supplying generation service to SSO customers and customers taking service under special contracts for the calculation period.
The competitive bidding process expenses.
The applicable interest for the calculation period at a monthly rate of 0.7066%.
The projected kWh sales for the period during which Rider GCR will be applied.
The Commercial Activity Tax rate as established in Section 5751.03 of the Ohio Revised Code.
The loss factor associated with each rate category based on service voitage. (See Pace 1 of Exhibit G to the Appiication in Case No. Q8-0935-EL-SSO1-
T'ne overail Ccmpany/Ohio average loss factor.
AVOIDAEILITY:
j-f the GCR Deferral Saiancs < (5% x Eg) for a given calculation oenod the GCR1 = GCR and GCR1 is not acDiled to cusiomers whc take generation from a certified supplier.
If the GCR Defarra! Balance > (5% x E ) for a given calculation period, then GCR2 = GCR and GCR2 is net avcjdacie 'or customers wrc tske gereration from a certified sucplier.
Raqardiess. in the event that a sucpiier that has been providing power as a result of the competitive bid process defaults during the applicable ESP cericd. the Company upon its belief that such default will cause the GCR Oeferrai Bafance to exceed the 5% threshold, mav determine that the GCR charge is not avoidable for custcmers who take generation from a certified supplier.
RIDERUPDATES:
I The charges contained in this Rider shall t)e updated and reconciled on a quarterly biasis. No later than December 1st, March 1st June 1st and September "tsrof each year, the Com p ^
I a request for approval of the Rider charges jA'hich, unless otherwise orelered by the PUCO, shall become effective on a service rendered basis on January 1st. April 1st, July Ist and October 1st of eadi year,
I b>eginning Qctotier 1, ^011.
/credSs
' Ddatad:/cred((s
Deleted: 2009
Filed pursuant to Order dated, in Case No. .before
The Public Utilities Commission of Ohio
Issued by: Richard R. Grigg, President Effective: June 1,2011
Ohio Ediscn Company
Akron, Ohio P.U.C.O. No. 11
Original Sheet 103
Page 1 of 2
RIDER GCR Generation Cost Reconciliation Rider
APPLICABILITY:
Applicable to any customer who receives electric service under the Company's rale schedules. The Generation Cost Reconciliation Rider (GCR) charge will apply, rate scheduj^ ®?^ctiye for service _ rendered beginning June 1,2011, for all kWhsperkWh,_ " " _ I I I I _ " I I I I I '
-(Deleted! for all
•(Deleted:
RATE: GCR1 GCR2
-5§'_QS,_ST_L, TRF, POL -^•2£££S^_ ^yssssl
1 Deleted: This Rider is not avoidabte far customers who take electric generation servk:e from a certified, supplier.
GP x.xxxxi^ x.xxxxii , W-u i lu n III •«.i-.ai' III i j 41 HI iiTlii,
-«r\ 1 Deleted! GCR charge:
GSU x.xxx>ji X;)0OQ _ - \\^ i Deleted: 0000
k ^ ^ . S \ , . m . — I I . .
GT X.XXXX x.:ooQ^ •-I'^^\N \ Formatted: Space After: 3 pt
\V^A t Deleted: 0
The GCR charge shall be calculated as follows:
GCR
Where:
i.
f[GCR Deferral Balancel / S} x_1/(1 : CAT) x ff 1 • LOSS^vr.) / f l • LOSS)> _
Deleted: 1DD6
Deleted: 1006
^ Deleted: 0000
Deleted: 1006
The calculation period is the three-month period ended two months prior to the effective dates of the updated rider (i.e. three months ended October 31, January 31, April 30, and July 31). Each component of the formula includes the aggregated data for The Cleveland Electric Illuminating Company, Ohio Edison Company, and The Toledo Edison Company. For any given billing period, oniv the non-zero GCR charge will be aoolied.
\ \M Deleted: 0000
^>.
•GCR Deferral Balance C(Bp-GCRpFv GENBFV +Eg + Er.Rp) + n
Bp = The actual reconciliation balance, including applicable interest, at the end of the previous calculation period.
GCRREV = The actual revenue associated with Rider GCR, as billed for the calculation period, excluding applicable Commercial Activity Tax
GENREV = The actual revenue associated with Riders GEN, RTP and CPP, as billed for the calculation period, excluding applicable Commercial Activity Tax.
Es = The actual cost of supplying generation service to SSO customers and
customers taking service under special contracts for the calculation period.
EcBP = The competitive bidding process expenses.
I = The applicable interest for the calculation period at a monthly rate of 0.7066%.
S = The projected kWh sales for the period during which Rider GCR will be charged.
CAT = The Commercial Activity Tax rate as established in Section 5751.03 of the Ohio Revised Code.
Formatted: Indent: Left: 0.5", Hanging: 0.38", Numbered + Level; 1 + Numbering Style: i, 11, Iii,... + Start at 1 + Alignment: Left + Aligned at: 0.5" + Tab after: 0.75" + Indent at- 0.75", Tabs: 0.88", List tab + Not at 0.75"
"{ Formatted; Bullets and Numbering j
Deleted: .-Section Break (Next Page}-j
Filed pursuant to Order dated , in Case No. , before
The Public Utilities Commission of Ohio
Issued by: Richard R. Grigg, President Effective: June 1,2011
Ohio Edison Company Original Sheet 103
Akron. Ohio P.U.C.O. No. 11 ^ Page 2 of 2
RIDER GCR Generation Cost Reconciliation Rider
LOSS = The loss factor associated with each rate category based on service voltage. fSee Page 1 of Exhibit C to the Application in Case No. 08-0935-EL-SSO).
LOSSflVf; = The overall Company/Ohio average loss factor.
AVOIDABILITY:
If the GCR Deferral Balance < (5% X Eg) for a given'calculation period the GCR1 =GCRandGCR1 is not applied to customers who take qeneTation from a certified supplier.
jf the GCR Deferral Balance > 15% x Eg> for a given calculation period, then GCR2 = GCR and GCR2 is not avoidable for customers who take generation from a certified supplier.
Regardless, in the event that a supplier that has been providing power as a result of the competitive bid process defaults during the applicable ESP period, the Company upon its belief that such default will cause the GCR Deferral Balance to exceed the 5% threshold, mav determine that the GCR charge is not avoidable for customers who take oeneration from a certified supplier.
RIDER UPDATES:
The charges contained in this Rider shall be updated and reconciled on a quarterly basis. No later than December 1st, March 1st, June IstandSeptember 1st of each year, the Company will file with the PUCO a request for approval of the Rider charges which, unless otherwise ordered by the PUCO, shall become effective on a sen/ice rendered basis on January 1st, April 1st, July 1st and October 1st of each year. beginning October 1.^Q1_1 _ . __ _ _ --fDeieted;2009
Filed pursuant to Order dated , in Case No. . before
The Public Utilities Commission of Ohio
Issued by: Richard R. Grigg, President Effective: June 1.2011
TTie Cleveland Electric Illuminating Company
Cleveland, Ohio P.U.C.O. No. 13
Sheet 103
•e^..^^',sgd Page 1 of. ?.
RfDERGCR Generation Cost ReconcUiatlon Rider
Deleted: 3"
Formatted: Superscript
APPLICABILITY:
Applicable to any customer who receives electric service under the Company's rate schedules. The Generation Cost Reconciliation Rider (GCR) charge will apply. rate schedule^, effectiye for seryice rendered beginning Jun5.1, 201^., for all kWhsper kWh.^
RATE:
RS. GS, STL. TRF, PCL
GP
GSU
GT
GCR1
^.xxxxjit
x.xxxxii
x.xxxxff
X.XXXX^
GCR2
x.xxxxi
X.XXXX^
x.xxxxit
x.xxxxii
The GCR charge shall be calculated as follows:
GCR = IL3CR Deferral Balancel / S^ x V ( i - CAT) x ^(1 - LOSS^uq) / (1 - LOSS))
Where:
L The calculation period is the three-month period ended two months prior to the effective dates o i the updated rider (i.e. three months ended October 31, January 31. April 30, and July 31).
ii. Each ccrr^conent of the formula includes the aggregated data for The Cleveland Electric liiuminating Company. Ohio Edison Company, and The Toledo Edison Company. For anv given biliinc ceriod, only the non-zero GCR charge will be applied.
Dieted: This Rider is nd avoidable ftH-cu^omers who taloe elftctric generaHbn sennca from a ceitHted supt^r
I: indent: Left: 0.5", Hanging: 0.36", Tabs: 0.83", List tab + Not at 1.23"
Formatted: Bidlets and Number^
FDrmatted: Bullets and Nund}eni
Filed pursuant to Order dated. _ » ' "
Issued by: ^
The Public UtiHties Commission of Ohio
PresJdert
before
Effisdive: June1.20;l1
The Cleveland Electric Illuminating Company
Cleveland, Ohio P.U.C.O. No. 13
Original Sheet 103
Page 2 of 2
RIDER GCR Generation Cost ReconcHiation Rider
GCR Deferral Baianca iREV •Li3_l_ic3Pi_Ll!
Bp = The actual reconciliation balance, including applicable interest, at the end of the previous calculation period.
GCRREV = The actual revenue associated with Rider GCR, as billed for the calculation period, excluding appiicabte CommerciaJ Activity Tax.
GENREV = The actual revenue associated with Riders GEN, RTP and CPP as billed for the calculation period, excluding applicable Comnlfercial Activity Tax.
Es = The actual cost of supplying generation service to SSO customers and
customers taking service under special contracts for the calculatton period.
EcBP = The competitive bidding process expenses.
I = The applicable interest for the calculation period at a monthly rate of 0.7066%.
S = The projected kWh sales for the period during which Rider GCR will be charged.
CAT = The Commercial Activity Tax rate as established in Section 5751.03 of the Ohio Revised Code.
LOSS = The loss factor associated with each rate category based on sspjice voltage. (See Page 1 of Exhibit C to the Application in Case No, 08-0935-EL-SSO_).
LOSSiv^ = T^e overall Company/Ohio average loss factor.
AVOIDABILITY:
if the GCR Deferral Balar)ce < (5% x E ) for a given caicuiation period the GCR1 = GCR and GCR1 is not gcclied to ciistorriers who take generation from a certified suoplier-
If the GCR tPeferral Balance > (5% x £ a for a given calculation period, then GCR2 = GCR and GCR2 is not avoidabie for cjstor'srs who take generation irom a certified supplier.
Regardless, in the event that a suoplier that has been providing power as a result of the competitive bid process defaults during the acDlicabie ESP period, the Company uoon its belief that such default will cause the GCR Deferral Balance to exceed the 5% threshold, mav determine that the GCR charge is not avQidafcle for customers who take generation from a certified suppiier.
RIDERUPDATES:
The charges contained in this Rider shall be updated and reconciled on a quarterly basis. No later than December 1st, March 1st, June 1st and September 1st of each year, the Company will file with the PUCO a request for approval of the Rider charges which, unless othenwise ordered by the PUCO, shall become effective on a service rendered basis on January 1st, April 1st, July 1st and October 1st of each year, beginning October 1, ,£011. Deleled:200g
Filed pursuarit to Order dated in Case No. before The Public Utilities Commission of Ohio
Issued by: Richard R. Grigg, President Effective: June 1.2011
This Optional Load Response Program Rider ("Program") is available to any customer taking service jrom _ , - ' - { Deleted; under the Compan^£,atprimarvyojtage_s_or higher voljajges provided tjiat^ll of t^^ met at the time of iinitiation of service~under thfs Rider and on a conlinuing basis thereafter "(i) the customer has at least one megawatt of Realizable Curtailable Load ("RCL"); (ii) the customer can successfully demonstrate to the Company that it can reduce its instantaneous measured load to a pre-established contract Firm Load (as defined under Other PnDvisions, paragraph A , below) withinJwo hours _ of notification provided by the Company without the need of h generator (A customer may intend to use a generator to reduce its usage to below its Firm Load, but if the generator does not operate, the customer must still reduce its usage to or below its Firm Load. Failure of a customer to reduce its usage to or below its Firm Load shall result in the consequences listed in the Emergency Curtailment Event Section herein.); (iii) the customer executes the Company's standard Program contract; and (iv) the customer is taking -generation service from the Company under the Generation Service Rider (GEN); (v) the customer is not participating in any other load curtailment program, including without limitation a demand response program offered bv PJM Interconnection, L.L.C. f"PJM"\orany otherindependent system operator; fvi) the customer commits its demand response capability to Comoanv for integration into Company's R.C. ^ 4928.66 compliance programs: and, (vii^ the Commission finds that the demand response capabilities of custgmers electing service under this rider shall count towards the Company's compliance with the peak demand reduction benchmarks set forth in R.C. S 4928.66 as applied bv the Commission's applicable rules and regulations and shall be considered incremental to interruptible load on the Company's system that existed in 2008. Nothing herein shall preclude a customer from reguesting and receiving an exemption from anv mechanism designed to recover the cost of enenjv efficiencv and peak demand reduction programs to the extent the exemption is reouested to reasonably encourage the commitment of customer-sited capabilities to the Comoanv. This Rider is not applied to customers during the period the customer takes electric generation service from a certified supplier.
Deleted; 's general service tariffs served
Deleted: the Midwest Independent Transn isston System Operator, Inc. ("MISO")
RATES:
In addition to any other charges under any other rate schedules applicable lo customer's service, customers participating in the Program shall also pay the charges and receive the credit set forth below:
Charges:
Program Administrative Charge:
ECE Charge:
$150.00 per month
During an Emergency Curtailment Event (as defined under Other Provisions,,paragraph D., below), the portion of the customer's actual measured load that exceeds its pre-established contract Firm Load for any and all hours during such event shall be assessed an ECE Charge which is calculated for each hour of the event as follows. Revenue collected bv the Company as a result of anv ECE Charge less amounts associated with the CAT fas defined belowl shall be credited towards costs to be collected through the DSE1 charge of Rider DSE:
ECE Charge Where:
(AL xPJMLMPx300%)x (1 + L A f i x i[1/i1_-CAT)l)^
AL = the customer's actual hourly load during an Emergency Event that exceeds the customer's pre-established contract Firm Load.
in Case No. , before
issued by:
_ _ - -{Deleted: MISQ
jpeletBd:May27,2Q09
/ J Deleted: 03-935-EL-SSO at al.
' / i Deleted: / / ' > ™ - - — /' •" i Deleted:
Richard R. Grigg
2009 H Filed pursuant to Order dated.,
The Public Utilities Commission of Ohio
, f Lssident ^ _'__ _ ^Effectfye: _June_t^011 j '
i ' I / It
u II
If
The Toledo Edison Company ^he_et 1p2_ . - - f Deleted: Original
CAT = the Commercial Activity Tax rate as established in Section 5751.03 of the Ohio - ^J '^ l^^; commercial Pricing Node Revised Code. TESR" (or its equivalent}
Deleted: May 27.2009
l { Deleted: oa'935-EL-SSO et al. ^ \
i f ( Deleted; Richard R. Grigg ^ J
//' / { Deleted: 2009 ) •f ' I
f ' I Filed pursuant to Order dated. ^ in Case No..^_ .before / //
LAF = Loss Adjustment Factor " 3.0% for primary voltages 0.1% for subtransmission voltages 0.0% for transmission voltages
Program Credit ("PC"):
Customers talking service under this Rider shall receive a monthly Program Credit which shail be calculated as follows: .
^ ^ - -( Formatted: Superscript
PC
Where:
RCL X ($1.95)/kW/month
RCL is the predetermined realizable curtailable load, which shall be calculated by the Company once per year for each customer by subtracting the customer's contract Fimi Load from its Average Hourly Demand ("AHD"). For purposes of this Rider, the AHD shall be the", customer's average kW load occurring during the non-holiday weekday hours of 11 a.m. to 5 p.m. Eastern Standard Time (equivalent to noon to 6 p.m. EDT) during the months of June through August, excluding actual hours of any Emergency Curtailment Events.occurring during the preceding 12 month period. The RCL shall not exceed the amount of a customer's billing demand in excess of the contracted Finn Load on a monthly basis. The customer shall be provided written notice each year by the Company of the value of the RCL at least thirty (30) days in advance of the effective date of the RCL.
Minimum Bill
The application of the Program Credit shall not produce a total monthly bill for any customer, after including the effects of all rate schedules and riders, that results in an average price per kWh less than tA o (2) cents per kWh.
O T H E R ' P R O V I S T O N S : " " " '
A.' Firm Load
For purposes of this Rider, "Firm Load" shall be that portion of a customer's electric load that is not subject to curtailment A customer may request a reduction lo its contract Finn Load no more than once In any twelve month period. The Finn Load may be reduced to the extent that such reduction is consistent with other terms and conditions set forth in this Rider. Any such change in Firm Load shall be applied beginning with the customer's January bill immediately following the year in which the change has been approved by the Company, provided that advance written request is provided to the Company no less than thirty (30) days prior to the effective billing month of the change. The Company may increase the Firm Load at any time If the Company, at its sole discretion, determines the Firm Load is at a level that the customer fails to demonstrate that they can reach. The Company shall promptly notify the customer of any such change.
B. Load Response Program Contract
Customers taking service under this optional rider shall execute the Company's standard Program contract which, among other things, will establish the Customer's Firm Load and commit the Customer's demand response capability to Company for purposes of Company's compliance with the peak demand reduction benchmarks set forth in R.C. S 4928.66 as applied by the Commission's applicable rules and regulations.
* 1 Formatted: Indent: Left: 0"
Filed pursuant to Order dated. jinpase_No_.^ before
- -f Deleted: If
Deleted: May 27.2009
Deleted: 08-g3S-EL-SSO et al.
Deleted; Richard R. Grigg
I / i Deleted! 2009 ' , ' / % I I . , , , . — . . . 1 1 — . . —
The customer must arrange for interval metering consistent with the Company's Miscellaneous Charges, Tariff Sheet 75.
D. Emergency Curtailment Event
Upon no less than jwo hour advance nqtificatign gCPY'ded by_ the Company^ a customer jaking - - ' i Deleted: ten minutes service under this rider musrcurtailall load above its Firm Load~d'uring an Emergency cJuftailrnent Event consistent with the Company's instructions. For purposes of this rider, an Emergency Curtailment Event shall be one in which the Company, a regional transmission organization and/or a transmission operator determines, in its respective sole discretion, that an emergency situation exists that may jeopardize the integrity of either the distribution or transmission system in the area^ If the Emergency Curtailment Event is requested solely bv the regional transmission organization. the maximum duration that load must be curtailed will be 6 hours and shall be limited to ten events per planning year as defined by PJM. Any interruptions reouested by the regional transmission organization will only occur between 12:00 PM fNoonl to 8:00 PM (Eastern Prevailing Time) for the months of Mav through September and 2:00 PM to 10:iX> PM for the months of October through April, on weekdays other than PJM IHolidavs.
During the entire period of an Emergency Curtailment Event, the customer's actual measured load must remain at or below its Finn Load with such load being measured every clock half hour. A customer's actual measured load shall be detenrtlned using the greater of the customer's highest lagging kVa or highest kW during the Emergency Curtailment Event.
If at any time during the Emergency Curtailment Event a customer's actual measured load exceeds Its contract Finn Load, the Company may disconnect the customer from the transmission system for the duration of the Emergency Curtailment Event, at the customer's expense. The Company shall not be liable for any direct or indirect costs, losses, expenses, or other damages, special or othenA-ise, including, without limitation, lost profits that arise from such disconnection.
If at any time during the Emergency Curtailment Event a customer's actual measured load exceeds 110% of its Firm Load, the customer shall be subject to all four (4) of the following; (i) forfeit its Program Credit for the month in which the Emergency Curtailment Event occurred; (ii) pay the ECE Charge set forth in the Rates section of this Riden (iii) pay the sum of all Program Credits received by the customer under the Program during the immediately preceding twelve billing months which shall include credits from this Rider; and [ N ) the Company's right, at its sole discretion, to remove the customer from the Program for a minimum of 12 months.
If at any time during the Emergency Curtailment Event a customer's actual measured load is greater than 100% and less than or equal to 110% of its Firm Load during the Emergency Curtailment Event, the customer shall forfeit its Program Credit for the month in which the Emergency Curtailment Event occurred and shall pay the ECE Charge set forth in the Rates section of this Rider.
In a calendar year when an Emergency Curtailment Event has not been reouested of customers on this Rider between June 1 and August 15. the Company shall simultaneously interrupt all customers on this Rider bv September 30 in order to meet the Company's PJM test obligations for Load Management Resources. The duration of this test will be one hour. The Company will schedule the test and Customers shall receive advance notification of the test All provisions of this Rider shall aoplv to this test.
Filed pursuant to Order dated, inpase_No^^ before
Deleted: IMay 27,2009
Peleted; Qa-935-EL-SSO el al.
' / { Deleted: Richard R. Grigg
/' ' I Deleted: 2009
Issued by: ,.
The Public Utilities Commission of Ohio
President- _ _ Effectiye: June_1j^aiJ.,
The Toledo Edison Company ^he_ei 10_2_ . - ' {Pe'eted: Original
Jn the_event_of anjconflictjietween tfieJerms_and conditions setfojthjn thisjjder^an^jsjiier ^---[Deleted:n service reliability reguirements and/or obligation's of the Company including all PJM^reouiremenFs that may be in effect, the latter shail prevail.
E. Notification
Customers served under this Rider shall be provided notification Emergency Curtailment Events by the Company. Customers shall be provided clock times of the beginning and ending of these events, except the Emergency Curtailment Event notification may be stated such that customers must curtail their actual measured load to its Firm Load inJwo hours from the time th_e_nj3titotiqn_ _ _ - -{Deleted; io minutes is issued. Receipt of Jiotifications set out in this paragraph shall be the soTe responsibiFity of the _ , -f Deleted: curtailment customer. ' •
Notification of an Emergency Curtailment Events consists of an electronic message issued by the Company to a device or devices such as telephone, facsimile, pager or email, selected and provided by the customer and approved by the Company. Two-way infonnation capability shall be incorporated by the Company and the customer in order to provide confinnatlon of receipt of notification messages. Operation, maintenance and functionality of such communication devices selected by the customer shall be the sole responsibility of the customer.
F. Term
This rider shall become effective for service rendered beginning June 1.2011 and siiall_exgire „ _ with service rendered through May 31.201'
•{ Deleted; 2009 ]
-[ Deieted; 2D11 j
A customer may terminate its participation in the Program upon no less thanJhirtvsix(36) months _ _ - - -[Deleted: twelve (12 advance written notice to the Company. Except as otherwise provided in this rider, a gualifying customer may return to the Program fter a hiatus jrom_the Prp9!?in.°f_3l l^ast^one (1J year_on ^ ^ - -{ Deleted: at any time the first day of their billing cycle upon at least thTrty'days"prior written notice of their intent to return.
G., Conditions
Payment by the customer of aii charges herein is a condition of service under this Optional Load Response Program Rider.
;( Deleted: May 27.2009 • ^ ]
,\{ Deleted! oe-935-EL-SSQ et al. ]
' ' { Peleted: Ridiard K Grigg )
••/ / i Deleted: 2009 ] f. ' I ^ •• 1
Filed pursuant to Order dated, .in Case No..^., > before j t, ^
This Optional Load Response Program Rider ("Program") is available to any customer taking service from Jhe Company^.atprjmaiy voltages or higher voltages provided thaj.gl|of_th^ ^opditions are ^ , - -met at the time of initiation of service to the customer under this Rider and on a continuing basis ~ ^ thereafter: (i) the customer has at least one megawatt of Realizable Curtailable Load ("RCL"); (ii) the customer can successfully demonstrate to the Company that it can reduce its instantaneous measured load to a pre-established contract Firm Load (as defined under Other Provisions, paragraph A., below) withinjwo hours qfnotificaUqnpro yided J^y jhe_Cornp_any witho_ut the jieed^ of _a^enerator (A cu_stomer m_ay _ intend to use a generator to reduce its usage to below its Finn Load, but if the generator does not operate, ^ the customer must still reduce its usage to or below its Firm Load. Failure of a customer lo reduce its usage to or below Its Firm Load shall result in the consequences listed in the Emergency Curtailment Event Section herein.); (iii) the customer executes the Company's standard Program contract; and (iv) the customer is taking generation service from the Company under the Generation Service Rider (GEN); (v) the customer is not participating in any other load curtailment program or demand response program. including without limitation a demand response program offered by the^PJM Interconnection. LL.C. . ("PJM") or any other independent system operator, (vii the customer commits its demand response capability to Company for integration into Company's R.C. ^ 4928.66 compliance programs: and, (vii) the Commission finds that the demand response capabilities of customers electing service under this rider shall count towards the Company's compliance with the peak demand reduction benchmarks set forth in R.C. S 4928-66 as applied bv the Commission's applicable rules and regulations and shall be considered incremental to inten-uptible load on the Company's system that existed in 2008. Nothing herein shall preclude a customer from reguesting and receiving an exemption from anv mechanism designed to recover the cost of energy efficiencv and peak demand reduction programs to the extent the exemption is requested to reasonably encourage the commitment of custcmer-sited capabilities to the Company, This Rider is not applied to customers during the period the customer takes electric generation service from a certified supplier.
Deleted: under
Deleted: 's
Deleted: general service tailffs served
Deleted: tl\e customer meets
Deleted: five
; ,. : "^^^
! :
Deleted: ten m'mutes
Deleted: Midwest Independent Transmlsston System Operator, Inc. f'MISO")
RATES:
in addition to any other charges under any other rate schedules applicable to customer's service, customers participating in the Pmgram shall also pay the charges and receive the credit set forth below:
Charges:
Program Administrative Charge: $150.00 per month
ECE Charge:
During an Emergency Curtailment Event (as defined under Other Provisions, paragraph D., below), the portion of the customer's actual measured load that exceeds its pre-established contract Finn Load for any and all hours during such event shall be assessed an ECE Charge which is calculated for each hour of the event as follows. Revenue collected by the Company _ _ „ - \ Deleted:^ as a result of anv ECE Charge less amounts associated with the CAT fas defined below) shall be credited towan^s costs to be collected through the DSE1 charge of Rider DSE.
CAT = the Ohio Commercial Activity Tax rate as established in Section 5751.03 of the Ohio Revised Code. Lo^s Adjustment_Fa_ctox 3.0% for primary voltages 0.1 % for subtransmission voltages 0.0% for transmission voltages
Program Credit rPC") :
Customers taking service under this Rider shall receive a monthly Program Credit which shall be calculated as follows:
PC = RCL X ($1.95) /kW/month
Where;
RCL is the predetennined realizable curtailable load, which shall be calculated by the Company once per year for each customer by subtracting the customer's contract Firm Load from its Average Hourly Demand ("AHD"). For purposes of this Rider, the AHD shall be the customer's average kW load occurring during the non-holiday weekday hours of 11 a.m. to 5 p.m. Eastern Standard Time (eguivalent to noon to 6 p.m. EDT) during the months of June through August, excluding actual hours of any Emergency Curtailment Events occurring during the preceding 12 month period. The RCL shail not exceed the amount of a customer's billing demand in excess of the contracted Firm Load on a monthly basis. The customer shall be provided written notice each year by the Company of the value of the RCL at least thirty (30) days in advance of the effective date of the RCL.
Minimum Bill
Deleted: Commercial Pricing Node 'FESR" (or its equivalent)
Formatted: Tabs: 3.18", Left
~ Deleted: I
.The application of the Program Credjt shall not produce a totaj rngG*h'y bjl' f°r anv customer^ after _^ , ^ -{Formatted: Font (Default] Arial induding the effects of all rate schedules and riders, that results in an average price per kWh less than tvi/o (21 cents per kWh.
OTHER PROVISIONS:
A. Firm Load
For purposes of this Rider, "Firm Load" shall be that portion of a customer's electric load that is not subject to curtailment A customer may reguest a reduction to its contract Firm Load no more than once in any twelve month period. The Finn Load may be reduced to the extent that such reduction is consistent with other terms and conditions set forth in this Rider. Any such change in Finn Load shall be applied beginning with the customer's January bill immediately following the year in which the change has been approved by the Company, provided that advance written reguest is provided to the Company no less than thirty (30) days prior to the effective billing month
, of the change. The Company may increase the Firm Load at any time if the Company, at its sole discretion, determines the Firm Load is at a level that the customer fails to demonstrate that they can reach. The Company shall promptly notify the customer of any such change.
B. Load Response Program Contract
Filed pursuant to Order dated, in Case No., , befiare
Deleted: May 27,2X9 ,f /,{Deleted! 08-g35-EL-5SO et al.
Customers taking service under this optional rider shall execute the Company's standard Program ccntract which, among other things, will establish the Customer's Firm Load and commit the Customer's demand response capability to Company for purposes of Company's compliance with ihe peak demand reduction benchmarks set forth in R.C. ^ 4928.66 as applied bv the Commission's applicable rules and regulations, . - - - ( Deleted;!
C. jyietering t u - ^ ' - f Deleted: Tl
The customer must arrange for interval metering consistent with the Company's Miscellaneous Charges, Tariff Sheet 75.
D. Emergency Curtailment Event
Upon no less than^wojiour advance,nqtificajion prj)yided_by_the Companyj_a customerJakin5_ _ service under this Rider must curtail allTo'ad above its Firm Load during an Emergency Curtailment Event consistent with the Company's instructions. For purposes of this Rider, an Emergency Curtailment Event shall be one in which the Company, a regional transmission organization and/or a transmission operator determines, in its respective sole discretion, that an emergency situation exists that may jeopardize the integrity of either the distribution or transmission system in the area. If the Emergency Curtailment Event is reouested solely bv the regional transmission grganization. the maximum duration that load must be curtailed will be 6 hours and shall be limited to ten events per planning year as defined bv PJM. Anv interruptions reouested by the regional transmission grganization will only occur between 12:00 PM fNoon) to S:00 PM (Eastern Prevailino Time) for the months of May through September and 2:00 PM to J 0:00 PM for the months of October through April, on weekdays other than PJM Holidays-
I Formatted: Bullets and l umbering
-'-i Deleted; ten minutes
During the entire period of an Emergency Curtailment Event, the customer's actual measured load must remain at or below its Firm Load with such load being measured every clock half hour. A customer's actual measured load shall be determined using the greater of the customer's highest lagging kVa or highest kW during the Emergency Curtailment EvenL
If at any time during the Emergency Curtailment Event a customer's actual measured load exceeds its contract Firm Load, the Company may disconnect the customer from the transmission system for the duration of the Emergency Curtailment Event, at the customer's expense. The Company shall not be liable for any direct or indirect costs, losses, expenses, or other damages, special or otherwise, including, without limitation, lost profits that arise from such disconnection.
If at any time during the Emergency Curtailment Event a customer's actual measured load exceeds 110% of its Firm Load, the customer shail be subject to all four (4) of the following: (1) forfeit its Program Credit for the month in which the Emergency Curtailment Event occurred; (11) pay the ECE Charge set forth in the Rates section of this Rider; (iii) pay the sum of all Pnsgram Credits received by the customer under the Program during the immediately preceding twelve billing months which shail include credits from this Rider; and (iv) the Company's right, at its sole discretion, to remove the customer from the Program for a minimum of 12 months.
If at any time during the Emergency Curtailment Event a customer's actual measured load is greater than 100% and less than or equal to 110% of its Firm Load during the Emergency Curtailment Event, the customer shall forfeit its Program Credit for the month in which the Emergency Curtailment Event occun-ed and shall pay the ECE Charge set forth in the Rates section of this Rider.
-[ Deleted: H
X Deleted: May 27.2009
/, Deleted: 0B-935-EL-SSO et al.
' / ( Deleted: Richard R. Grigg ]
; / ' i Deleted: 2009 ]
Filed pursuant to Order dated ^ ^inCase_t^o^^. before
Issued by: ThePublic Utilities Commission of Ohio
Presidenj '_ §^ctiye:_June_1j^01J._
I h • ' /
II
Ohio Edison Company
Akron, Ohio
^heet 102_ . ' ' i Deleted: Original
P.U.C.O. No. 11
RIDER OLR Optional Load Response Program Rider
In a calendar year when an Emergency Curtailment Event has not been reouested of customers on this Rider between June 1 and August 15. the Comoanv shall simultaneously interrupt all customers on this Rider by September 30 in order to meet the Company's PJM test obligations for Load Management Resources. The duration of this test will be one hour. The Company WJH scheduie the test and Customers shall receive advance notification of the test. AH provisions of this Rider shall apply to this test
In the event of any conflict between the tenns and conditions set forth in this Rider and other service reliability requirements and/or obligations of the Company including all PJM requirements that may be in effect, the latter shall prevail.
Customers served under this Rider shall be provided notification Emergency Curtailment Events by the Company. Customers shall be provided clock times of the beginning and ending of these events, except the Emergency Curtailment Event notification may be stated such that customers must curtail their actual measured load to its Firm Load iniwo hours from the time th_e_n_otitation_ is issued. Receipt of/iptifications set out in this paragraph shajl be thes'ojeresponsibijily ofthe customer. : :
Deleted: 10 minutes
Deleted: entailment
Notification of an Emergency Curtailment Event consists of an electronic message issued by the Company to a device or devices such as telephone, facsimile, pager or email, selected and provided by the customer and approved by the Company. Two-way infonnation capability shall be incorporated by the Company and the customer in order to provide confirmation of receipt of notification messages. Operation, maintenance and functionality of such communication devices selected by the customer shall be the sole responsibility of the customer.
F. Term
This Rider shall become effective for service rendered beginning June 1 ..2011 and shall expire - - — j Deleted: 2DD9 with service rendered through May 31 ,^0^4^ -| Deleted*
A customer may terminate its participation in the Program upon no less than^hirtysixyBS) mpD^hs _ ^ \ Deleted: 2011 advance written notice to the Company. Except as otherwise provided in this Rider, a qualifying ^N~ ~ ~| Deleted: twelve customer may return to the Pragram^fter a hjatusJrpmjhe P[P9[an]_ofat i^ast_one (IJ year_on "* J 0_im_j. --the first day of their billino cvcie upon at least thirty davs prior written notice of their intentlo return. "^^ y
"[ Deleted: al any time
G. Conditions
Payment by the customer of all charges herein is a condition of service under this Optional Load Response Program Rider.
This Optioaal Load Response Program Rider ("Program") is available to any customer taking service^rom the Compan^at_^r[manivojtagesorh|gher_voltajg_esprovided tjiatjallof thefolbw[ng^even_^conditio_ns^re_ met at the time of initiation of service under this Rider and on a continuing basis thereafter, (i) the customer has at least one megawatt of Realizable Curtailable Load ("RCL"); (ii) the customer can successfully demonstrate to the Company that it can reduce its instantaneous measured load to a pre-
I established contract Firm Load (as defined under Other Provisions, paragraph A,, below) withiniwo hours of notification provided by the Company without the need of a generator (A customer may intend to use a generator to reduce its usage to below its Fimi Load, but if the generator does not operate, the customer must still reduce its usage to or below its Firm Load. Failure of a customer to reduce its usage to or below its Firm Load shall result in the consequences listed in the Emergency Curtailment Event Section herein.); (iii) the customer executes the Company's standard Program contract; and (iv) the customer is taking generation service from the Company under the Generation Service Rider (GEN); (v) the customer is not participating in any other load curtailment program or demand response program, induding without
limitation a demand response program offered by PJM Interconnection. LL.C. f"PJM"loranv other_ independent system operator, (vi^ the customer commits its demand response capability to Company for integration into Company's R.C. ^ 4928.66 compliance programs: and, fvil) the Commission finds that the demand response capabilities of customers electing service under this rider shall count towards the Company's compliance with the peak demand reduction benchmarks set forth in R.C. $ 4928.66 as applied bv the Commission's applicable rules and regulations and shall be considered incremental to interruptible load en the Company's system that existed in 2008. Nothing herein shall preclude a customer from requesting and receiving an exemption from anv mechanism designed to recover the cost of energy efficiencv and peak demand reduction programs to the extent the exemption is reouested to reasonably sncouraqg fr-e commitment o1 customer-sited capabiiities to the Company. This Rider is not applied to customers during the period the customer takes electric generation service from a certified supplier.
Deleted: under -{ Deleted;
-j Deleted: 's general service tariffs
Deleted: the custaner meets
Deleted: ten minules
Deleted: the Midwest Indep^dent Transmission System Opersdor, Inc. {"MISO")
RATES:
In addition to any other charges under any other rate schedules applicable to customer's service, customers participating in the Program shall also pay the charges and receive the credit set forth below;
Charoes:
Program Administrative Charge:
ECE Charge;
$150.00 per month
During an Emergency Curtailment Event (as defined under Other Provisions, paragraph D.. below), the portion of the customer's actual measured load that exceeds its pre-established contract Firm Load for any and all hours during such event shall be assessed an ECE Charge which is calculated for each hour of the event as follows. Revenue cpllected by the Company as a result of any ECE Charge less amounts associated with the CAT fas defined below) shall be credited tov^ards costs to be collected through the DSE1 charge of Rider DSE.
ECE Charge Where:
(AL x P M LMP X 300%) X (1 +.LAF1X {[1/{1_-CAT)]i.
- - -{Peleted;
AL = the customer's actual hourly load during an Emergency Event that exceeds the customer's pre-established contract Finn Load.
Filed pursuant to Order dated^. in Case No., before
Issued by:
The Public Utilities Commission of Ohio
^PLesident _ __ _Effectiy%:_June_1j 011_
Deleted: MISO
Deleted: May 27,2009
Deleted: 08-935-EL-SSO et at
peleted; Richard R. Grigg
{Deleted! 2009
The Cleveland Electric Illuminating Company
Cleveland, Ohio
^heet 102_ , - - jPe'eted: Original'
P.U.C.O. No. 13
RIDER OLR Optional Load Response Program Rider
£JiyLLiyPis_^he final DayAheadj-ocationalMargiiiaj Price_as_defined_and ^ specified bvPJM at the appropriate pricing nod^durinq^the ag|3licabje_hqur(s)!
CAT = the Commercial Activity Tax rate as established in Section 5751.03 of the Ohio Revised Code,
Deleted: Commercial Pricing Node "FESR' (or its equivalent)
Filed pursuant to Order dated, inCase_NQ_. , before
j Deleted: May 27,2009
, ,1 Deleted: 08-935-EL-SSO et al |
Deleted: Richard R. Gr^g j
•I ' / ^ Deleted: 2009
Issued by: ^
The Public Utilities Commission of Ohio
^ President _ _ Effedtiye;_June;ij^g11._,'
The Cleveland Electric Illuminating Company
Cleveland, Ohio P.U.C.O. No. 13
^heetl02.
l / ' Revised Page 3 of 5
- -( Deleted; Ortg^l
- - ••{ Formatted: Superscript
RIDER OLR Optional Load Response Program Rider
LAF = Loss Adjustment Factor 3.0% for primary voltages 0.1% for subtransmission voltages 0.0% for transmission voltages
Program Credit ("PCM:
Customers taking service under this Rider shall receive a monthly Program Credit which shall be calculated as follows:
PC = RCL X ($1.95) /kW/month
Where:
RCL is the predetermined realizable curtailable load, which shall be calculated by the Company once per year for each customer by subtracting the customer's contract Fiim Load from its Average Hourly Demand ("AHD"). For purposes of this Rider, the AHD shall be the customer's average kW load occurring during the non-holiday weekday hours of 11 a.m. to 5 p.m. Eastern Standard Time (equivalent to noon to 6 p.m. EDT) during the months of June through August, excluding actual hours of any Emergency Curtailment Events occurring during the preceding 12 month period. The RCL shall not exceed the amount of a customer's billing demand in excess of the contracted Firm Load on a monthly basis. The customer shall be provided written notice each year by the Company of the value of the RCL at least thirty (30) days in advance of the effective date of the RCL
Minimum Bill
The application of the Program Credit shall not produce a total monthly bill for any customer, after including the effects of all rate schedules and riders, that results in an average price per kWh less than two (2) cents per kWh.
" O T H E R PROVISIONS:"
A. Firm Load
For purposes of this Rider, "Finn Load" shall be that portion of a customer's electric load that is not subject to curtailment A customer may reguest a reduction to its contract Finn Load no more than once in any twelve month period. The Firm Load may be reduced to the extent that such reduction is consistent with other terms and conditions set forth in this Rider. Any such change in Firm Load shall be applied beginning with the customer's January bill immediately following the year in which the change has been approved by the Company, provided that advance written request is provided to the Company no less than thirty (30) days prior to the effective billing month of the change. The Company may increase the Finn Load at any time if the Company, at its sole discretion, determines the Finn Load is at a level that the customer fails to demonstrate that they can reach. The Company shall promptly notify the customer of any such change.
B. Load Response Program Contract
Customers taking service under this optional rider shall execute the Company's standard Program contract which, among other things, vk'ill establish the Customer's Finn Load and commit the Customer's demand response capability to Company for punaoses of Company's compliance with the peak demand reduction benchmarks set forth in R.C. S 4928.66 as applied bv the Commission's applicable rules and regulations.
Fomtatted: Indent Left: 0'
'] Deleted: ^
Filed pursuant to Order dated, in Case No., before
Issued by:
Ttie Public Utilities Commission»of Ohio
President Effectiye: June 1.:2011
,{ Deleted: May 27.2009 ]
/ j Deleted: oa-935-EL-SSO et al.
'7 { Deleted: Richard R. Grigg
y ; { I>Bleted: 2009 f- ' / •
- i 1/
• ' . ' ;
II It
1 )
The Cleveland Electric Illuminating Company
Cleveland, Oliio P.U.C.O. No. 13
iSheet 1_02_ , - ' J Pe'eted: Original
llPeyiag^F-age-4. of j , ^ - ^ -JFormatted: Superscript
RIDER OLR Optional Load Response Program Rider
C. Metering
The customer must arrange for interval metering consistent with the Company's Miscellaneous Charges, Tariff Sheet 75.
D. Emergency Curtailment Event
Upon no less than Jwo iipur advance notificajion provided,byjhe Company^a custornerjak[n_g , - -j Deleted; ten minutes service under this rider musfcurtail all load above its Firm Load during an Emergency Curtailment Event consistent with the Company's instructions. For purposes of this Rider, an Emergency Curtailment Event shall be one in which the Company, a regional transmission organization and/or a transmission operator determines, in its respective sole discretion, that an emergency situation exists that may jeopardize the integrity of either the distribution or transmission system in the area^ If the Emergency Curtailment Event is reouested solely bv the regional transmission organization. the maximum duration that load must be curtailed will be 6 hours and shall be limited to ten events per planning year as defined bv PJM. Anv interruptions reouested bv the regional transmission organization will only occur between 12:00 PM fNoon^ to 8:00 PM (Eastern Prevailing Time) for the months of Mav through September and 2:00 PM to 10:00 PM for the months of October through April, on vreekdavs other than PJM Holidays.
During the entire period of an Emergency Curtailment Event, the customer's actual-measured load must remain at or below its Finn Load with such load being measured every clock half hour. A customer's actual measured load shall be determined using the greater of the customer's highest lagging kVa or highest k\N during the Emergency Curtailment Event
If at any time during the Emergency Curtailment Event a customer's actual measured load exceeds its contract Firm Load, the Company may disconnect the customer from the transmission system for the duration of the Emergency Curtailment Event, at the customer's expense. The Company shall not be liable for any direct or indirect costs, losses, expenses, or other damages, special or otherwise, including, without limitation, lost profits that arise from such disconnection.
If at any time during the Emergency Curtailment Event a customer's actual measured load exceeds 110% of its Firm Load, the customer shall be subject to all four (4) of the following: (i) forfeit its Program Credit for the month in which the Emergency Curtailment Event occurred; (ii) pay the ECE Charge set forth in the Rates section of this Rider; (iii) pay the sum of all Program Credits received by the customer under the Program during the immediately preceding twelve billing months which shall include credits from this Rider; and (iv) the Company's right, at its sole discretion, to remove the customer from the Program for a minimum of 12 months.
If at any time during the Emergency Curtailment Event a customer's actual measured load is greater than 100% and less than or equal to 110% of its Firm Load during the Emergency Curtailment Event, the customer shall forfeit its Program Credit for the month in which the Emergency Curtailment Event occurred and shall pay the ECE Charge set forth in the Rates section of this Rider.
In a calendar year when an Emergency Curtailment Event has not been reouested of customers on this Rider between June 1 and August 15, the Company shall simultanegusly interrupt all customers on this Rider bv September 30 in order to meet the Company's PJM test obligations for Load Management Resources. The duration of this test will be one hour. The Company will schedule the test and Customers shail receive advance notification of the test All previsions of this Rider shail apply to this test
j Deleted: May 27. 2009
Deleted: oe-93S-EL-SSO et al. ^ Deleted; Richard R. Grigg
Deleted: 2D0S
Filed pursuant to Order daled^ in Case No. before f
JQ IhS-SveMof ar)y_cpnflict_between the terms_and coridrtions set fcyljijn t_his_rider an_d_other service reliability requirements and/or obligations of the Company including all PJ'M" reguirements that mav be in effect the latter shall prevail.
E. Notification
^he_etl0_2_
I'lggvisedJage^S of 5_ - -j Formatted: Superscript
-| Deleted: H
Customers served under this Rider shall be provided notification Emergency Curtailment Events by the Company. Customers shall be provided clock times of the beginning and ending of these events, except the Emergency Curtailment Event notification may be stated such that customers must curtail their actual measured load to its Firm Load in JEwo hours from the time th_e_notificatiqn_ is issued. Receipt of jiotifications set out in this paragraph shall be jhie_s_oIe_res|X)nsibiri of the ~ ' customer.
- ^ Deleted: 10 minules
"[ Deleted: curtailment
Notification of an Emergency Curtailment Events consists of an electronic message Issued by the Company to a device or devices such as telephone, facsimile, pager or email, selected and provided by the customer and approved by the Company. Two-way infonnation capability shall be incorporated by the Company and the customer in order to provide confirmation of receipt of notification messages. Operation, maintenance and functionality of such communication devices selected by the customer shall be the sole responsibility of the customer.
F.' Term
This rider shall become effective for service rendered beginning June I.^OIJ^and shall expire , - - -{ Deleted; 20DS with service rendered through May 31 ,2011 I I _ I I " , ^ " " I - - . { 7 ^ e d ; 2 0 i i
A customer may terminate its participation in the Program upon no less thanihirtv six f36) mpntfis _ _ - - •{ Deleted: twelve (12 advance written notice to the Company. Except as o^erwise provided in this rider, a qualifying customer may return to the Program^fter a hiatus frpmjhe Prp5ranigf_a^ l?ast_one i1}year_on , ,.- -{ Deleted; at any lime the first day of their billing cycle upon at least thirty days prior written notice of their intent to return.
Conditions
H
payment by the customer of all charges herein is a condition of service under this Optional Load Response Program Rider.
,( Deleted: l flay 27. 2009
,/1 Deleted:
V \ Deleted: / . / j - I I I
08-g35-EL-SSO et al.
Richard R. Grigg
' i ' ' { Deleted: 2D09 J
in Case No., h ' I
before } //
Issued by:
Filed pursuant to Order dated,
The Public Utilities Commission of Ohio
, President ' Effe^iye: _June_1_,^ort '
The Toledo Edison Company
Toledo, Ohio P.U.C.O. No. 8
RIDER ELR Economic Load Response Program Rider
APPLICABILITY:
iSheet 1_0_1_ _ - ' J Pe'^^ed; Original
-iJ-RgJtisg^FjgS-1 of j - - - •- •TFo''matted; Superscript
This Economic Load Response Program Rider ("Program") is available to customers taking service Jronn the Companitat_|Dr[m_a_rYyoJtages_o_r hisb^Lvoltagesprovided thatjallof thefoliowing^sgvenconditjonsare met at the time of initiation of service to the customer under this Rider and on a continuing basis thereafter: (i) the customer took service under the Company's interruptible tariffs set forth below as of February 1, 2008 or the customer took service under an interruptible contract with the Company as of February 1, 2008 that subsequently expired or was terminated; (Ii) the customer can successfully demonstrate to the Company that it can reduce its instantaneous measured load to a pre-established contract Firm Load (as defined under Other Provisions, paragraph A , below) withinJwo hours of notification provided by the Company without the need of a generator (A customer may intend to use a" generator to reduce its usage to below its Firm Load, but if the generator does not operate, the customer must still reduce its usage to or below its Firm Load. Failure of a customer to reduce its usage to or below its Firm Load shall result in the consequences listed in the Emergency Curtailment Event Section herein.); (iii) the customer executes the Compan/s standard Program contract; (iv) the customer is taking generation service from the Companitj^ltj iecusjqmerjs notparticipatmg jnan^other [oad curtajlment^oi; _ demand response program. Including without fimitatiorra demand response program offere'd by PJM Interconnection. L.L.C. f'PJM"lQr any other Independent jysjern operator: fvi) the customer commits its demand response capability to Company for integration into Company's R.C. 5 4928.66 compliance programs: and, fviil the Commission finds that the demand response capabilities of customers electino service under this rider shall count towards the Company's compliance with the peak demand reduction benchmarks set forth in R.C. ? 4928.66 as applied by the Commission's applicable rules and regulations and shall be considered incremental to intennjptible load on the Company's system that existed in 2008. Nothing herein shall preclude a customer from reguesting and receiving an exemption from anv mechanism designed to recover the cost of energy efficiency and peak demand reduction programs to the extent the exemption is reouested to reasonably encourage the commitment of customer-sited capabilities to the Company.
Deleted: under
Deleted: 's general service tariffs served
•f Deleted', twv rr\tnutes
Deleted: tmderttie Generation Sen/Ice Rider (GEN)
Deleted: and
Deleted: the Midwest independent Transnf)ission System Operator, Inc. ("MISO.")
Inten-uptibie Power Rate TV-46" Original Sheet No. 63
RATES:
In addition to any other charges under any other rate schedules applicable to customer's service, customers participating in the Program shall also pay the charges and receive the credit set forth below:
Charges:
Program Administrative Charge:
EBT Charge:
$150.00 per month
During an Economic Buy Through Option Event (as defined under Other Provisions, paragraph E., below), the portion of the customer's actual measured load that exceeds its pre-established contract Firm Load for any and all hours during such event shall be assessed an EBT Charge, which is calculated for each hour of the event as follov/s:
Filed pursuant to Order dated, in_Case_No^ before
Issued by:
^fpeleted: May 27.2009
;\{ Deleted; 08-935-EL-SSO et al.
' / { Deleted; Richard R. Grigg
/ / ' / Deleted: 2009
The Public Uttllties Commission of Ohio
President ' _Effective: vlun6_1j 011._
J It If
The Toledo Edison Company
Toledo, Ohio P.U.C.O. No. 8
^he_etlO_1_
1. ' Revised P3ge_2 of j .
- •{ Deleted! Original
- ' "{ Formatted: ^perscript
EBT Charge
Where:
RIDER ELR Economic Load Response Program Rider
= (AL X MPD) X (1 + U F ) X ([1/(1 • CAT)])
AL = the customer's actual hourly load during an Economic Buy Through Option Event that exceeds the customer's pre-established contract Firm Load.
WIPD = the market price differential, which shall be calculated by subtracting the applicable charges set forth in the Generation Service Rider (GEN) from the PJM ^ _ LMP for the period in which the Economic Buy Through Option Event occurred for each hour that results in a MPD greater than zero.
PJM LMP is the finaj pay^Ahead j.pcatipnal^1argjnal Pnce_as_djffined_and , specified bvPJM at the appropriate pricing node."dumq^lhe agp_licabje_hqur(s). ^
CAT - the Commercial Activity Tax rale as established in Section 5751.03 of the Ohio Revised Code.
-i Deleted: MISO
Deleted: MISO
Deleted: MISO
Deleted: Commercial Pricing Node TE5R' (or Its equivalent)
LAF ^
ECE Charge:
Loss Adjustment Factor 3.0% for primary voltages 0.1% for subtransmission voltages 0.0% for transmission voltages
During an Emergency Curtailment Event (as defined under Other Provisions, paragraph D., below), the portion of the customer's actual measured load that exceeds its pre-established contract Firm Load for any and all hours during such event shall be assessed an ECE Charge which is calculated for each hour of the event as follovtfs. Revenue collected by the Company as a result of any ECE Charge less amounts associated with the CAT fas defined above) shall be credited towards costs to be collected through the DSE1 chame of Rider DSE:
Customers taking service under this Rider shail receive a monthly Program Credit which shall be calculated as follows:
PC = CL X (15.00) /kW/mo nth - - -\ Deleted: 1.95
Where:
CL is the Curtailable Load, which shall be calculated by the Company for each customer by subtracting the customer's contract Firm Load from its monthly highest thirty (30) minute integrated kW load occurring during the non-holiday weekday hours of 11 a.m. to 5 p.m. Eastern Standard Time (equivalent to noon to 6 p.m. EDT). In no circumstance can the CL be negative nor can the CL be in excess of a contract amount determined based upon the customers 12 month history as of February 1,2008. Holidays are defined as New Year's Day. Memorial Day, Independence Day, Labor Day, Thanksgiving Day and Christmas Day.
Minimum Bill
The application of the Program Credit shall not produce a total monthly bill for anv customer, after including the effects of all rate schedules and riders, that results in an average price per kWh less than two (2Vcents per kWh.
OYHYR" PROVISIONS:
* ( Formatted: Indent: Lfift: 0"
- -( Deleted; Tj
A. Firm Load
For purposes of this rider, "Finn Load" shall be that portion of a customer's electric load that is not subject to curtailment. A customer may request a reduction to its contract Firm Load no more than once in any twelve month period. The Firm Load may be reduced to the extent that such reduction is consistent with other terms and conditions set forth in this Rider. Any such change in Firm Load shall be applied beginning with the customer's January bill immediately following the year in which the change has been approved by the Company, provided that advance written request Is provided to the Company no less than thirty (30) days prior to the effective billing month of the change. The Company may increase the Firm Load at any time if the Company, at its sole discretion, detenmines the Finn Load is at a level that the customer fails to demonstrate that they can reach. The Company shall promptly notify the customer of any such change.
B. Load Response Program Contract
Customers taking service under this optional^idersjiaH execute jhe_Cqrnf)any's stand_aj;d - - ' A Detetedi r Program contract which, among other things, will esfablish the Custorner's~FTrm Load and commit the Customer's demand response capability to Company for punooses of Company's compliance with the peak demand reduction benchmarks set forth in R.C. ^ 4928.66 as applied bv the Commission's applicable rules and regulations.
C. Metering
The customer must arrange for interval metering consistent with the Company's Miscellaneous Charges, Tarifl^ Sheet 75.
j Deleted; May 27.2D09
f\{ Deleted; OS-gsS-EL-SSO et al.
' / ( Deleted: Richard R. Grigg
/ ' ' / { ^ •t ' 1 ^ —
Deleted: 2009
in Case No. J before j
Issued by:
Filed pursuant to Order dated,
The Public Utilities Commission of Ohio
_ ' President __ _EITecliye: _June^1j2D11 /
The Toledo Edison Company
Toledo, Ohio P.U.C.O. No. 8 ^heel lQI .
jf_RevisedJ^_age.4 of_S_
- ' 1 Deleted; Original
^ - ' ' i Formatted: Superscript
RIDER ELR Economic Load Response Program Rider
D. Emergency Curtailment Event
Upon no less than-two hour advance notification oroyided bv the Cpmpan^j^ a customer jak|n_g service under this rider must curtail all load above its Firm Load'd'uring an Emergency Curtailment Event consistent with the Company's instructions. For purposes of this rider, an Emergency Curtailment Event shall be one in which the Company, a regional transmission organization and/or a transmission operator determines, in its respective sole discretion, that an emergency situation exists that may jeopardize the integrity of either the distribution or transmission system in the area. If the Emergency Curtailment Event is reouested solely bv the regional transmission organization. the maximum duration that load must be curtailed will be 6 hours and shall be limited to ten events per planning year as defined by PJM. Anv intemjptions requested bv the regional transmission organization will only occur between 12:00 PM (Noon) to 8:00 PM fEastern Prevailing TimeHor the months of May through September and 2:00 PM to 10:00 PM for the months of October through April, on weekdays other than PJM Holidays.
During the entire period of an Emergency Curtailment Event, the customer's actual measured load must remain at or below its Firm Load with such load being measured every clock half hour. A customer's actual measured load shall be determined using the greater of the customer's highest lagging kVA or highest kW during the Emergency Curtailment Event
If at any time during the Emergency Curtailment Event a customer's actual measured load exceeds its contract Firm Load, the Company may disconnect the customer from the transmission system for the duration of the Emergency Curtailment Event, at the customer's expense. The Company shall not be liable for any direct or indirect costs, losses, expenses, or other damages, special or othenAfise, including, without limitation, lost profits that arise from such disconnection.
If at any time during the Emergency Curtailment Event a customer's actual measured load exceeds 110% of its Firm Load, the customer shall be subject to all four (4) of the follovt^ng: (i) forfeit its Program Credit for the month in which the Emergency Curtailment Event occurred; (ii) pay the ECE Charge set forth in the Rates section of this Rider; (iii) pay the sum of all Program Credits received by the customer under the Program during the immediately preceding twelve billing months which shall include credits from this Rider and the Economic Development Rider; and (iv) the Company's right, at its sole discretion, to remove the customer from the Program for a minimum'of 12 months.
If at any time during the Emergency Curtailment Event a customer's actual measured load is greater than 100% and less than or equal to 110% of its Firni Load during the Emergency Curtailment Event, the customer shall forfeit its Program Credit for the month in which the Emergency Curtailment Event occurred and shall pay the ECE Charge set forth in the Rates section of this Rider.
Deleted: ten m^utes
In a calendar year when an Emergency Curtailment Event has not been reouested of customers on this Rider between June 1 and August 15, the Company shall simultaneously interrupt all custpmers on this Rider bv September 30 in order to meet the Company's PJM test obiioations for Load Management Resources. The duration of this test will be one hour. The Company will schedule the test and Customers shall receive advance notification of the test. All provisions of this Rider shall apply to this test, Jn the_eyent_ofanxcpnflictbetween thetermsand conji|tipns sejfoj ihjn th[s_Riderand other_ service reliabiHty requirements and/or obligations of the C'ompani; th"e_latter shalljorevail.
E. Economic Buy Through Potion Event
Filed pursuant to Order dated, inCase__No^^ . before
The Public Utilities Commissioaof Ohio
•( Deleted; F
4 Deleted: Including ait PJM requirements that may be In effect
Deleted: May 27,2009
Deleted: 0S-935-EL-SSO et al.
Deleted: Richard R. Grigg
Deleted: 2009
f It t ' I
Issued by: Presidenl Effective: _June_1_,^01J._,'
The Toledo Edison Company
Toledo. Ohio P.U.C.O. No. 8
^heet1_0J_
llReylsedJageSofS.
- ' iPsleted: Original
-{ Formatted: Superscript
RIDER ELR Economic Load Response Program Rider
Upon no less than a 90 minute advance notification provided to the customer, the Company shall call an Economic Buy Through Option Event ("EBT") v\^en a "Martlet Premium Condition" exists. A Market Premium Condition is defined as a point in time that the^JM-LMP exceeds theproduct_ _ _ _ - -{Deleted: MISO of 1.5 times the wholesale price resulting from the Company's competitive bid process held" for generation service commencing on June 1,.2011 and updated anytime there is aprice change in ^ - -(Deleted: 2DD9 generation service. The number of hours of EBT cannot exceed 10% of the hours in any twelve month period beginning in June of each calendar year.
F. Notification
Customers served under this Rider shall be provided notification of Economic Buy Through Option Events and Emergency Curtailment Events by the Company. Customers shail be provided clock times of the beginning and ending of these events, except the Emergency Curtailment Event notification may be stated such that customers must curtail their actual measured load to its Firm Load in Jwo hours fromjiietmie the notification is issued. Receipt of jiotifications set out in this paragraph shall be the sole responsibility of the customer ' " "
-{Deleted: 10 minutes 'I Dele^d: curtailment
Notification of an^_conqniic Buy^Through_Option Eyenj and_ EmergencyjCurtaijrnenj Even] consists of an electronic message issued by the Company to a device or devices such"as telephone, facsimile, pager or email, selected and provided by the customer and approved by the Company. Two-way infonnation capability shall be incorporated by the Company and the customer in order to provide confirmation of receipt of notification messages. Operation, maintenance and functionality of such communication devices selected by the customer shall be the sole responsibility of the customer.
' 'I Deleted: inlerruption
G. Term
This rider shall become effective for service rendered beginning June 1 ,^Qllj_an^js_hall_expire _ _ , _ - •\ Deleted; 2009 with service rendered through May 31.^014 . . " ' I ' ~ f d'20ii
A customer may terminate its participation in the Program upon no less thanihirtY5ix(3S} montj}s _ , - -{tJe^eted; twelve ti2 advance written notice to the Company. Except as othenwise provided in this^ider^ a giJal'^LnS - t D e l e t e d l r " " " customer may return to the Program^fter a hiatus_frornJhe Program^of at [east one i ^ Jyea r^ j the first day of the, customer's billing cycle upgn^^atreastlhirtYdays prior'written notice of the. _ " I ~ ~ " ' l "^e'eted: at any time customer's intent to return. " Deleted: »-
H. Conditions [ Deleted: ir
Payment by the customer of ail charges herein is a condition of service under this Economic Load Response Program Rider.
Filed pursuant to Order dated, ^ >D Case_No^,„
The Public Utilities Commission of Ohio t>efore
a / Deleted: May 27.2009
Deleted: 08-g35-EL-SSO et al.
Deleted: Richard R. Grigg
Deleted: 2009 5 f ' /
J ' I 1/
I t
Issued by: Presidenj " Effe(aiye: June 1.2011 ?
Ohio Edison Company
Akron, Ohio P.U.C.O. No. 11
^heet lOJ _ , - ' { Deleted: Qriginar
I^RemedPaoel of 5
RIDER ELR Economic Load Response Program Rider
APPLICABILITY:
This Economic Load Response Program Rider ("Program") is available to customers taking service from ^he_Cqr nI an^ at_l5 i_^na_ryyoJtages_or higher_vpl]a_ges provided t^atA'LPl lheJollp\M_ng.^eveix.condit]ojis are_ met af the time ofinitiation of service to"ttie customer under thIs'Rider'and on a continuing basis' thereafter: (i) the customer took service under the Company's interruptible tariffs set forth below as of February 1, 2008; (i!)^he cystgrnerj^nsuccessjullydemonsjrat^totheConipany^tJiatJtcanj-educe[ts ___ instantaneous measured lo'ad to a pre-established contFact Finn Load (as'defined under Ottier Provisions,' paragraph A , below) withinJwo hours of nqtificatipn provided by_the Cpmpany_withpyt_the need of a generator (A customer may intend to use a generator to'reduce its uiage to below its Firm Load" butlf'the generator does not operate, the customer must still reduce its usage to or below Its Firm Load. Failure of a customer to reduce its usage to or below its Firm Load shall result in the consequences listed in the Emergency Curtailment Event Section herein.); (iii) the customer executes the Company's standard Program contract; (iv) the customer is taking generation service from the Company;^vJ^h_e_custpmer is not participating in any other load curtailment or demand response program, including without limitation a demand response program offered by^JM Interconnection. L.L.C. TPJM") or any other independent system operator fvi) the customer commits its demand response capability to ComVanv for InFegraliorT into Company's R.C. ^ 4928.66 compliance programs: and, fvii) the Commission finds that the demand response capabilities of customers electing service under this rider shall count towards the Company's compliance with the peak demand reduction benchmarks set forth in R.C. 5 4928.66 as applied bv the Commission's applicable rules and regulations and shall be considered incremental to interruptible load on the Company's system that existed in 2008. Nothing herein shall preclude a customer from reguesting and receiving an exemption from any mechanism designed to recover the cost of energy efficiency and peak demand reduction programs to the extent the exemption is reouested to reasonably encourage the commitment of customer-sited capabilities to the Company.
Deleted: under
" Deleted:'s general service tariffs served
_ - - -j Deleted: under the Generation S^ lce Rider (GEN)
Deleted: and
Deleted: the Midwest Independent Transmission System Operator, Inc. ("MISO")
Formatted: Not Highlight
interruptible Electric Arc Furnace Rate
Interruptible Rider - General Service Large and High Use Manufacturing
Interruptible Rider-Metal Melting Load
Internjptible Rider- Incremental Interruptible Service
Original Sheet No. 29
Original Sheet No. 73
Original Sheet No. 74
Original Sheet No. 75
RATES:
In addition to any other charges under any other rate schedules applicable to customer's service, customers participating in the Program shall also pay the charges and receive the credit set forth below:
Charges:
Program Administrative Charge:
EBT Charge:
$150.00 per month
During an Economic Buy Through Option Event (as defined under Other Pravisions, paragraph E., below), the portion of the customer's actual measured load that exceeds its pre-established contract Firm Load for any and all hours during such event shall be assessed an EBT Charge, which is calculated for each hour of the event as follows: #BT C_h_arae_ = {AL x MPDJ x {1_+ LAF)_x_(I1_/(1.-.CAT)D /
Where:
•I Deleted: H
/ \ Deleted; -- Page Break
Deieted: May 27,2009
/,{ Deleted: 08-935
Deleted: Richard R. ^ g g
Deleted: June 1,2CK39
Filed pursuant to Order dated., , in Case No., -EL-SSO et_aj.Lb_efore_
The Public Utilities Commission of Ohio
f ••/ _/ ' t
I I •I
Issued by: President Effective:
Ohio Edison Company
Akron, Ohio
iSheel lOJ.. . - - J Deleted: Drisinal
P.U.C.O. No. 11 1 Revised Page 2 of 5
RIDER ELR Economic Load Response Program Rider
AL = the customer's actual houriy load during an Economic Buy Through Option Event that exceeds the customer's pre-established contract Firm Load.
MPD
CAT =
the market price differential, which shall be calculated by subtracting the applicable charges set forth in the Generation Service Rider (GEN) from the,PJM _ LMP for the period in which the Economic Buy Through Option Event occurred for each hour that results in a MPD greater than zero.
the Ohio Commercial Activity Tax rate (CAT) as established in Section 5751.03 of the Ohio Revised Code.
Deleted: MISO
Deleted: MISO
Deleted: Cammerciai Pricing Node "FESR' (or its equrvateni)
LAF = Loss Adjustment Factor 3.0% for primary voltages 0.1% for subtransmission voltages 0.0% for transmission voltages
ECE Charge:
During an Emergency Curtailment Event (as defined under Other Provisions, paragraph D., below), the portion of the customer's actual measured load that exceeds its pre-established contract Firm Load for any and all hours during such event shall be assessed an ECE Charge which is calculated for each hour of the event as follows. Revenue collected bv the Company as a result of any ECE Charoe less amounts associated with the CAT (as defined above) shall be credited towards costs to be collected through the DSE1 chame of Rider DSE - -(Deleted; l
ECE Charge {AL x P J M L M P x 3 0 0 % l x M + LAF^ x {[1/i1-CATl])_ „ . - -| Deleted: MISO
^(peleted: May27,2009
/,f Deleted: 08-935
' / f Deleted: Richard R. Grigg
' / / -(Deleted; June 1.2009 H Filed pursuant to Order dated^ _inCase_Np._3^
' Issued by: ^
The Public Utilities Commission of Ohio
Preside_nt ' _Effectiyej ^
4 ' /
EL-SSO et al.,_b_efpre _ J i l 'I
Ohio Edison Company
Akron, Ohio
^he„et.lO_1_ , - - i Deleted: Origii^
P.U.C.O. No. 11 1 Revised Page 3 of 5
RIDER ELR Economic Load Response Program Rider
Program Credit ("PC"):
Customers taking service under this Rider shall receive a monthly Pragram Credit which shall be calculated as follows:
PC = CL X (15.00^ /kW/month
Where:
'-(Deleted: 1.95
CL is the Curtailable Load, which shall be calculated by the Company for each customer by subtracting the customer's contract Firm Load from its monthly highest thirty (30) minute integrated kW load occurring during the non-holiday weekday hours of 11 a.m. to 5 p.m. Eastern Standard Time (equivalent to noon to 6 p.m. EDT). In no circumstance can the CL be negative nor can the CL be in excess of a contract amount determined based upon the customers 12 month history as of February 1,2008. Holidays are defined as New Year's Day, Memorial Day, Independence Day, Labor Day, Thanksgiving Day and Christmas Day.
The application of the Program Credit shall not produce a total monthly bill for anv customer, after including the effects of all rate schedules and riders, that results in an^veraoe price per kWh less _ _ - - - ( Formatted; Font (Default) Arial than two (2) cents per kWh.
OTHER PROVISIONS:
A. Firm Load
For purposes of this rider, "Firm Load" shall be that portion of a customer's electric load that Is not subject to curtailment. A customer may request a reduction to its contract Firm Load no more than once in any twelve month period. The Firm Load may be reduced lo the extent that such reduction is consistent with other terms and conditions set forth in this Rider. Any such change in Firm Load shail be applied beginning with the customer's January bill immediately following the year in which the change has been approved by the Company, provided that advance written request is provided to the Company no less than thirty (30) days prior to the effective billing month of the change. The Company may increase the Firm Load at any time if the Company, at its sole discretion, detemiines the Finn Load is al a level that the customer fails to demonstrate that they can reach. The Company shall promptly notify the customer of any such change.
B. Load Response Program Contract
Customers taking service under this optional Rider shall execute the Company's standard Program contract which, among other things, will establish the Customer's Firm Load and commit the Customer's demand response capability to Company for purposes of Company's compliance with the peak demand reduction benchmarks set forth in R.C. ^ 4928.66 as applied by the Commission's applicable rules and reoulations-
C. .Meterinq -
The customer must arrange for interval metering consistent with the Company's Miscellaneous Charges, Tariff Sheet 75.
Deleted: ]
\ Formatted: Bullets and Numbering |
[Deleted: May 27.2009
Deleted: 06-935
Deleted: Richard R. Grigg
Deleted: June 1.2009
Filed pursuant to Order dated^ in Case No., .-EL-SSO et_a]. before_ t
Issued by:
Tbe Public Utilities Commission of Ohio
President Effective:
Ohio Edison Company
Akron, Ohio
•§hiet. lOJ _ , - ' i Peleted: OriglnaT
P.U.C.O. No. 11 1 Revised Page 4 of 5
RIDER ELR Economic Load Response Program Rider
D. Emergency Curtailment Event
Upon no less t han^o hour advance_notification prpyided_l5yjhe Cgmpanj j a customer takjn^^ service under this Rider must curtail all load above itsl^Jrm Load during an Emergency Curtailment Event consistent with the Company's instructions. For purposes of this Rider, an Emergency Curtailment Event shall be one in which the Company, a regional transmission organization and/or a transmission operator determines, in its respective sole discretion, that an emergency situation exists that may jeopardize the integrity of either the distribution or transmission system in the area. If the Emergency Curtailment Event is requested solely by the regional transmission organization, the maximum duration that load must be curtailed will be 6 hours and shall be limited to ten events per planning year as defined bv PJM. Any interruptions requested bv the reoional transmission organization will only occur between 12:00 PM (Noon^ to 8:00 PM (Eastern Prevailing Time) for the months of May through September and 2:00 PM to 10:00 PM for the monthsof October through April, on y^ekdavs other than PJM Holidays. duringtheentjreperiod_qf j in Emejasncy_Curtallment_E_yentj^thecustqrner'_s_aj;tual_mea.sured__ load must remain at or below its Finn Load wifh such load being measured every clock half hour. A customer's actual measured load shall be determined using the greater of the customer's highest lagging kVA or highest kW during the Emergency Curtailment EvenL
•{ Deleted: len minutes
^ - -( Deleted:
If at any time during the Emergency Curtailment Event a customer's actual measured load exceeds Us contract Firm Load, the Company may disconnect the customer from the transmission system for the duration of the Emergency Curtailment Event, at the customer's expense. The Company shall not be liable for any direct or indirect costs, losses, expenses, or other damages, special or othenA/ise, including, without limitation, lost profits that arise from such disconnection.
If at any time during the Emergency Curtailment Event a customer's actual measured load exceeds 110% of its Firm Load, the customer shall be subject to all four (4) of the following: (i) forfeit its Program Credit for the month in which the Emergency Curtailment Event occurred; (Ii) pay the ECE Charge set forth in the Rates section of this Rider; (iii) pay the sum of all Program Credits received by the customer under the Program during the immediately preceding tvrelve billing months which shall include credits from this Rider and the Economic [development Rider; and (iv) the Company's right, at its sole disaetion, to remove the customer from the Program for a minimum of 12 months.
If at any time during the Emergency Curtailment Event a customer's actual measured load is greater than 100% and less than or equal to 110% of its Firm Load during the Emergency Curtailment Event, the customer shail forfeit its Program Credit for the month in which the Emergency Curtailme7\t Event occurred and shall pay the ECE Charge set forth in the Rates section of this Rider.
In a calendar year when an Emergency Curtailment Event has not been requested of customers on this Rider between June 1 and August 15, the Company shall simultaneously interrupt all customers on this Rider by September 30 in order to meet the Company's PJM test obligations for Load Management Resources. The duration of this test will be one hour. The Company vtfill schedule the test and Customers shall receive advance notification of the tesL All provisions of this Rider shall apply to this test.
In the event of any conflict between the terms and conditions set forth in this Rider and other , ~ = — - ^ ^ ^ = = = = = service reliability requirements and/or obligations of the Compan^t th_e_latte_r shallj3reva[l. / (peleted: May 27,2009
Deleted: including all PJM requirements that may be in effect
E. Economic Buy Through Option Event /i Deleted: 08-935
Deleted: Richard R. Grigg
Deleted: June 1,2009
Filed pursuant to Order dated- JnCaseJ*Jp.j_ -EL-SSO et_aj. before_
The Public Utililies Commission of Ohio
Issued by: President Effective:
If ' i f I I
} ' I i i
II It
t
Ohio Edison Company
Akron, Ohio P.U.C.O. No. 11
^heel lOJ _. - - ' { Deleted: Qfiginal
1'" Revised Page 5 of 5
- - - Deleted: MISO
, - -{Deletedi 09
RIDER ELR Economic Load Response Program Rider
Upon no less than a 90 minute advance notification provided to the customer, the Company shall call an Economic Buy Through Option Event ("EBT") when a "Mari^et Premium Condition" exists. A Market Premium Condition is defined as a point in time that the£JM LMP exceeds the product. of 1.5 times the wholesale price resulting from the Company's competitive bid process held for generation service commencing on June 1, 201% and updated anytime there is a price change in generation service. The number of hours of EBT cannot exceed 10% of the hours in any twelve month period beginning in June of each calendar year.
F. Notification
Customers served under this Rider shall be provided notification of Economic Buy Through Option Events and Emergency Curtailment Events by the Company. Customers shall be provided clock times of the beginning and ending of these events, except the Emergency Curtailment Event notification may be stated such that customers must curtail their actual measured load to its Finn . Load inJwo hours from_the_tin2e_the not[ficatK)njs issued. Receipt^of/lotificatjons set out In this - - - Deleted: io minutes paragraph shall be the sole responsibility ol ttie customer. ~ ~ '\ Deleted; curtailment
Notification of an Economic Buy ThroughOptipn Event and_ Emer^encyCurtaiinnent Event consists of an electronic message Issued by the Company to a device or devices such'as telephone, facsimile, pager or email, selected and provided by the customer and approved by the Company. Two-way information capability shall be incorporated by the Company and the customer in order to provide confirmation of receipt of notification messages. Operation, maintenance and functionality of such communication devices selected by the customer shall be the sole responsibility of the customer.
-{ Deleted; interruption
G. Term
This Rider shall become effective for service rendered beginning June 1, .2011. and 5liaJI_exgire_ with service rendered through May 31, 2 0 1 ^
^ Deleted: 2009 Deleted: 1
A customer may terminate its participation in the Program upon no less thanihirtv s ix^6) montjps ^ , ^ -advance written notice to the Company. _Except as othenvise provided in this Rider, a qualifying customer may return to the Program;after a hjaLus frpmjhe Program.of_at ieastpne (1J year on _ the first day of the.customer's billing cycle upo~n al Feast thirty davs prior written notice of tha customer's intent to return.
H. Conditions
Payment by the customer of al Response Program Rider.
charges herein is a condition of service under this Economic Load
"v i Deleted: at any time
N i Deleted: ir
t Deleted;
-{ Deleted:
Filed pursuant to Order dated^ . in Case No.. -EL-SSO et_a].,_b_efore_ i
Issued by:
The Public Utilities Commlssion-of Ohio
Presidejit '_ -Effective; j _
Deleted: May 27,20D9
Deleted; 08-935
Deleted; Richerd R. Qigg
Deleted: June 1,2(H)9 S
The Cleveland Electric Illuminating Company
Cleveland. Ohio
^he_et 10_1 _ ^ - ' \ P^'gted: Orlginat
PU.CO.No.13 llReyisgcLP.age^ 1_ of j _ , - -(Formatted: Superscript
RIDER ELR Economic Load Response Program Rider
APPLICABILITY:
This Economic Load Response Program Rider ("Program") is available to customers taking service^rom _ the Compan>;atj3ri_ma_ry_yo]tage_s_o_r hl3her_vpltagiesprovided t]iat_ li_qf thefoilowing^even conditions^re_ met at the time of initiation of service to the custom'er under thisRider and on a continuing basis thereafter; (i) the customer took service under an interruptible contract with the Company as of February 1.2008; (ii) the customer can successfully demonstrate to the Company that it can reduce its instantaneous measured load to a pre-established contract Finn Load (as defined under Other Provisions,
I paragraph A., below) withinJwo hours of notification provided by^the Company_withput_the_needpf a generator (A customer may intend to use a generator to'reduce its usage to below Its Firm Load, but if the generator does not operate, the customer must still reduce its usage to or below its Firm Load. Failure of a customer to reduce its usage to or below its Firm Load shall result in the consequences listed in the Emergency Curtailment Event Section herein.); (iii) the customer executes the Company's standard Program contract; (iv) the customer is taking generation service from the Company;;^vjth_e_custpmer^is not participating in any other load curtailment or demand response program, including without limitation a demand response program offered bvPJM interconnection. L.LC. ("PJM"Vor anv other independent system operator: (vi) the customer commits its demand response capability to Company for inFeoration into Company's R.C, ^ 4928.66 compliance programs: and, (vii) the Commission finds that the demand response capabilities of customers electing service under this rider shall count tovi^rds the Company's compliance with the peak demand reduction benchmarks set forth in R.C. S 4928.66 as applied bv the Commission's applicable rules and regulations and shall be considered incremental to intenruptible load on the Company's system that existed in 2008. Nothing herein shall preclude a customer from reguesting and receiving an exemption from anv mechanism designed to recover the cost of energy efficiencv and peak demand reduction oroorams to the extent the exemption is reouested to reasonabh? encourage the commitment of customer-sited capabilities to the Company.
- , - - -
^:i 1
---i
Deleted: under
Deleted: 's general service tariffs served
Deleted: the customer meets
Deleted: five
Deleted: ten minutes
Deleted: undw the Generation service Rider ((^N)
Deleted: and
Deleted; the Midwest Independent Tranamiaston Syslem Operstor, Inc. ("MISO")
RATES:
In addition to any other charges under any other rate schedules applicable to customer's service, customers participating in the Program shall also pay the charges and receive the credit set forth below:
Charges:
Program Administrative Charge:
EBT Charge:
$150.00 per month
During an Economic Buy Through Option Event (as defined under Other Provisions, paragraph E., below), the portion of the customer's actual measured load that exceeds its pre-established contract Firm Load for any and ail hours during such event shall be assessed an EBT Charge, which is calculated for each hour of the event as follows:
the customer's actual houriy load during an Economic Buy Through Option Event that exceeds the customer's pre-estabiished contract Firm Load.
the mart<et price differential, which shall be calculated by subtracting the applicable charges set forth in the Generation Service Rider (GEN) from the£JM _ - - -{ Deleted; MiSO LWIP for the period in which the Economic Buy Through Option Event occurred for each hour that results in a MPD greater than zero.
£ilM.L'yPl5_the Ijnaj Day Ahead_Lpcatipnal jiAarginaJ Price_^s_d_efined_and specified bvPJ'M at the appropriate pricing nod^jiurinq the agiTlicabje hoj jr§j ] ,
the Commercial Activity Tax rate as established in Section 5751.03 of the Ohio Revised Code.
LAF Loss Adjustment Factor 3.0% for primary voltages 0.1% for subtransmission voltages 0.0% for transmission voltages
ECE Charge:
During an Emergency Curtailment Event (as defined under Other Provisions, paragraph D., below), the portion of the customer's actual measured load that exceeds its pre-established ojntract Firm Load for any and all hours during such event shall be assessed an ECE Charge which is calculated for each hour of the event as follows. Revenue collected by the Comoanv as a result of anv ECE Charoe less amounts associated with the CAT (as defined above) shall be credited towards costs to be collected through the DSE1 charge of Rider DSE:
Customers taking service under this Rider shall receive a monthly Program Credit which shall be calculated as follows:
PC =
Where:
CL X (15.00) /kW/month . ^ - - f Deleted: 1.95
CL is the Curtailable Load, which shall be calculated by the Company for each customer by subtracting the customer's contract Firm Load from its monthly highest thirty (30) minute integrated kW load occurring during the non-holiday weekday hours of 11 a.m. to 5 p.m. Eastern Standard Time (equivalent to noon to 6 p.m. EDT). In no circumstance can the CL be negative nor can the CL be in excess of a contract amount determined based upon the customers 12 month history as of February 1,2008. Holidays are defined as New Year's Day, Memorial Day, Independence Day, Labor Day. Thanksgiving Day and Christmas Day.
Minimum Bill
The appiication of the Program Credit shall not produce a total monthly bill for anv customer, after including the effects of all rate schedules and riders, that results in an average price per kWh less than two (2) cents per kWh.
OTHER PROVISIONS: - -[ Deletedril
A. Finn Load
For purpcses of this Rider, "Firm Load" shall be that portion of a customer's electric load that is not subject to curtailment. A customer may request a reduction to its contract Firm Load no more than once in any twelve month period. The Firm Load may be reduced to the extent that such reduction is consistent with other terms and conditions set forth in this Rider. Any such change in Finn Load shail be applied beginning with the customer's January bill immediately following the year in which the change has been approved by the Company, provided that advance vifl"itten request is provided to the Company no less than thirty (30) days prior to the effective billing month of the change. The Company may increase the Rrm Load at any time if the Company, at its sole discretion, determines the Firm Load is at a level that the customer fails to demonstrate that they can reach. The Company shall promptly notify the customer of any such change.
B. Load Response Program Contract
Customers taking service under this optional Rider shall execute the Company's standard Program contract which, among other things, will establish the Customer's Finn Load and commit the Customer's demand response capability to Company for purooses of Company's compliance with the peak demand reduction benchmarks set forth in R.C. 9 4928.66 as applied by the Commission's applicable rules and regulations.
C. Metering
The customer must arrange for interval metering consistent with the Company's Miscellaneous Charges, Tariff Sheet 75.
^(peleted; May 27.2009
, ' \ Deleted; 08-935-EL-SSO et;
1/ { Deleted; Richard R. Grigg , l \ I. • m m ^ r T ' i j j i i
/ ' \ Deleted; 2009
in_Case_No^ before
Issued by: ^
Filed pursuant to Order daled^
The Public Utilities Commission of Ohio
, f resident I ^Effective: June 1,2011 .
I t
The Cleveland Electric Illuminating Company
Cleveland, Ohio P.U.C.O. No. 13
he_et1_0J_
l** Revised Page 4 of 5
- " *{ Deleted: Original
RIDER ELR Economic Load Response Program Rider
D. Emergency Curtailment Event
Upon no less thaniwo hour advance notification provided^ by^the Compan^^a custqn]erjak]njg_ _ service under this Rider must curtail all Toad above its Fimn Load during an Emergency Curtailment Event consistent with the Company's instructions. For purposes of this Rider, an Emergency Curtailment Event shall be one in which the Company, a regional transmission organization and/or a transmission operator detennines, in Its respective sole discretion, that an emergency situation exists that may jeopardize the integrity of either the distribution or transmission system in the area. If the Emergency Curtailment Event is reouested solely bv the regional transmission organization, the maximum duration that load must be curtailed will be 6
- - •{ Formatted: Superscript
-" '"{ Deleted: ten minutes
hours and shail be limited to ten events per planning year as defined bv PJM. Any interruptions reouested bv the reoional transmission organization will only occur between 12:00 PM (Noon) to 8:00 PM (Eastern Prevailino Time^ for the months of Mav through September and 2:00 PM to 10:00 PM for the months of October through April, on weekdays other than PJM Holidays.
During the entire period of an Emergency Curtailment Event, the customer's actua! measured lead must remain at or below its Finn Load with such load being measured every clock half hour. A customer's actual measured load shall be determined using the greater of the customer's highest lagging kVA or highest kW during the Emergency Curtailment Event.
If at any time during the Emergency Curtailment Event a customer's actual measured load exceeds its contract Firm Load, the Company may disconnect the customer from the transmission system for the duration of the Emergency Curtailment Event, at the customer's expense. The Company shall not be liable for any direct or indirect costs, losses, expenses, or other damages. special or othen^/ise, including, without limitation, lost profits that arise from such disconnection.
If at any time during the Emergency Curtailment Event a customer's actual measured load exceeds 110% of its Firm Load, the customer shall be subject to all four (4) of the following: (i) forfeit Its Program Credit for the month in which the Emergency Curtailment Event occurred; (ii) pay the ECE Charge set forth in the Rates section of this Rider; (iii) pay the sum of ail Program Credits received by the customer under the Program during the immediately preceding twelve billing months which shall include credits from this Rider and the Economic Development Rider; and (iv) the Company's right, at its sole discretion, to remove the customer from the Program for a minimum of 12 months.
If at any time during the Emergency Curtailment Event a customer's actual measured load is greater than 100% and less than or equal to 110% of its Firm Load during the Emergency Curtailment Event, the customer shall forfeit its Program Credit for the month in which the Emergency Curtailment Event occurred and shall pay the ECE Charge set forth in the Rates section of this Rider.
In a calendar year when an Emergency Curtailment Event has not been reouested of customers on this Rider between June 1 and August 15. the Company shall simultaneously inten'upt all customers on this Rider by September 30 in order to meet the Company's PJM test obligations for Load Management Resources. The duration of this test will be one hour. The Company will schedule the test and Customers shall receive advance notification of the test. All provisions of this Rider shall apply to this test Jn the_eyent_of an_y_q)nflict_betweei] the_terms_and conditions set forth jnt_hi_s_Ride_r_and other_ service reliability requirements and/or obligations of the'Companit thS i^er shall j3revail._ _ [
E. Economic Buy Through Option Event
Deleted: H
Filed pursuant to Order dated^ in Case No. before
Issued by:
Tb^ Public Utilities Commission of Ohio
President Effective:
Deleted: Induding all PJM requirements that may be in effect
Deleted: May 27,2009
Deleted: DB-935-Et-SSO et at.
Deleted; Richard R. Grigg
Deleted: 2009
Junel.^011
The Cleveland Electric Illuminating Company
Cleveland, Ohio
Sheet IQI_ . - - J Oe'eted: Original
P.U.C.O. No. 13 llBsyjsed_Pjige_5 o f j ^ - - •" 1 Pormatted: Superscript
RIDER ELR Economic Load Response Program Rider
Upon no less than a 90 minute advance notification provkied to the customer, the Company shall call an Economic Buy Through Option Event ("EBT") when a "Market Premium Condition" exists. . A Market Premium Condition is defined as a point in time that the,PJM!_LMP exceeds thepro_duct_ _ _ _ - -[ Deleted; Miio of 1.5 times the wholesale price resulting from the Company's competitive bid process held for . generation service commencing on June 1.^011 and undated anytime there is a pricechangein__^.-..-(Deleted; 2 0 ^ generation sen/ice. The number of hours of EBT cannot exceed 10% of the hours in any twelve month period beginning in June of each calendar year.
F. Notification
Customers served under this Rider shall be provided notification of Economic Buy Through Option Events and Emergency Curtailment Events by the Company. Customers shall be provided clock times of the beginning and ending of these events, except the Emergency Curtailment Event notification may be stated such that customers must curtail their actual measured load to its Firni Load inJwo hours from_the_t[nie_the notification is issued. Recgipt^of/totifications set out in tiiis paragraph shall be the sole responsibility of the customer.
•\ Deleted; 10 nnlnutes
"I Deleted: curtailment
Notification of an^cpnqmic Buy Ihroug[h_Optipn Event and Emergei]cy_Curtai]rnenj Event consists of an electronic message issued bythe Company to a device or "devices such as telephone, facsimile, pager or email, selected and provided by the customer and approved by the Company. Two-way infonmation capability shall be incorporated by the Company and the customer in order to provide confirmation of receipt of notification messages. Operation, maintenance and functionality of such communication devices selected by the customer shall be the sole responsibility of the customer.
-[ Deleted; fritemiption
G. Term
This Rider shall become effective for service rendered beginning June 1.^011. and shajl_expire_ with service rendered through May 31 ..2014.
"(i Deleted: 2009
Deleted: 2011
H. Conditions
Payment by the customer of all charges herein is a condition of service under this Economic Load Response Program Rider.
A customer may terminate its participation in the Program upon no less thaatliirtysix^36) months _ , - - -(Deleted: twelve (12 advance written notice to the Company. Except as otherwise provided in this Rider, a quall^ing customer may return to the Program fter a hiatus frpmjhe Prograrn qf_at leastone ( I j j /earon ^ - - •{ Deleted: at any time the first day of the, customer's billing cycle uponVt Feast thirty davs prior written notice of frie. customer's intent to return.
-fpe 'fpe
Deleted: Ir
Deleted: w Z1
Filed pursuant to Order dated, ^inpase_No^^ before
This Rider is not available to customers during the period the customer takes electric generation service from a certified supplier. This Rider is not available to customers during the period the customer is taking service under Rider ELR or Rider CPP.
The Experimental Real Time Pricing Rider (RTP) shall be applied in lieu of the Generation Service Rider (GEN) to customers participating in this voluntary experimental program.
PROGRAM DESCRIPTION:
I The RTP Program is voluntary and will be offered on an experimental basis through May 31 ..gQ14,_unles% _ , - -fpeleted; 2011 eariier terminated by the Company. Its purpose is to test customer response to houriy price signals
I quoted by PJM Interconnection. L.L.C. fPJM") or any other applicable Independent system operatocto ^ supply electricity. Participation in the RTP Program offers customers the opportunity to manage their electric costs by either shifting load from higher price to lower price periods or by adding new load during lower price periods.
Deleted: the Midwest Independent Transmission System Operator, Inc. rWldwest ISO")
RATE:
In addition to any other charges under all other rate schedules applicable to customer's service, exclusive of Rider GEN, customers taking service under this Rider shall also pay the charges set forth be\ow.
Charges:
Program Administrative Charge: $150.00 per month
RTP Billing:
Customers taking sen/ice under this Riderwili be billed based on the following calculation:
RTP Bill = Program Charge + RTP Energy Charge + RTP Fixed Charge + All Applicable Riders
, in Case No_. Filed pursuant to Order dated,;
The Public Utilities Commissio'n of Ohio
before
Deleted: January 20, 2010
Deleted; 09-54l-£l^TA Deleted; Richard R. Grigg I
'/ '} < ', '4 Deleted: Febmary
; . • / ) ] .1 — I . N I I M M . I II i:
/' / / •( Deleted; 2010 ]
'It
Issued by: ^ Presidenl _ __ _E_ffectiye: June 1. ,2011/
The Toledo Edison Company . he^et 1JJ_ , - ' {Peleted; Original
The RTP Energy Charge (RTPEC) is equal to the customers hourly energy usage applied to the houriy energy price quotes made publicly available bvPJM. as defined in the LMPi_definidqn_belo_vv. ^ _ - -{Deleted: Midwest 150
The RTPEC is calculated as follows:
RTPEC = S(kWh,xLMPO
Where:
kWht = Customer's kilowatt-hour usage in hour t t = An hour in the billing period n = Total number of hours in the billing period LMPt = the "Day-Ahead" Locationat Marginal Price, or "LMP" in hour t as defined and
specified byJ*JM at the appropriate pricing node, asjhis jnpde^ iriay^ be_ ch_anged_qr_ _ , - -[Deleted; the Midwest iso superseded from time lo time bypJM. In the event there is an errorTn the LMP """ -. J „ „ , ^ ^ r««. l ™«i D^-^^ M ^= . . . _ , . , ., - r-";; r • • 7 ~J~L.~ "r-Tiri."- ^ Deleted: Commercial Pncing Node reported bvPJM^the Company_s_ha|l agpjysucli prices_as correcte_d_by£JM_in monthly billings.
labeled "FESR"
Deleted: the Midwest ISO
based quotes. The customer is responsible for its access to the Internet for access to.pJM •( peieted; the Midwest ISO
" j Deleted: Midwest ISO
The Company shall not be responsible for failure of the customer to receive and act upon market \ [ Deleted: the Midwest iso based( pricing.
RTP Fixed Charges:
The following RTP Fixed Charges will apply, by rate schedule, for all kWhs per kWh:
* ^ \ ' ^ Deleted; 2.8919 j For billing purposes, the winter rates shall be applicable beginning with service rendered September 1 vs ^f n ted- 2 47S3 throuoh service rendered for Mav 31. The summer rates shail apolv in all other billina oeriods. \ \ 1 P* eted; 2. 7S3 ) through service rendered for May 31. The summer rates shall apply in all other billing periods.
^ \ Deleted; 2.BBU
{ Deleted; 2.4693
( Deleted; January 20,201D J
/ ( Deleted: D9-541-EL-ATA J
' / f Deieted: Richard R. Grigg j '/ If
! ' ,M Deleted: Febmary ]
/ , ' /J Deleted; 2010 1 { ' I t
i I ' I Filed pursuant to Order dated, , in Case No., , before J 1// I " 4/
The Public Utilities Commission of Ohio • *t [ Issued by: , , President Effectiye: June 1.^011 /
The Toledo Edison Company Original Sheet 111
Toledo. Ohio P.U.C.O. No. 8 Page 3 of 3
RIDER RTP Experimental Real Time Pricing Rider
METERING:
The customer must arrange for interval metering consistent with the Company's Miscellaneous Charges, Tariff Sheet 75.
TERMS AND CONDITIONS:
Failure by the customer to timely pay all amounts due within thirty (30) days of when due may be cause for removal from service under this Rider, at the option of the Company.
A customer may terminate service under this Rider effective with the next scheduled meter reading fcllowing at least 12 days notice to the Company by the customer. Customers who withdraw or are removed from the RTP Program may not return lo the RTP Program.
Filed pursuant to Onder dated January 20,2010, in Case No. 09-541-EL-ATA, before
The Public Utilities Commission of Ohio
Issued by: Richard R. Grigg, President Effective: Febmary 1, 2010
Ohio Edison Company
Akron, Ohio P.U.C.O. No. 11
•iShe_et1_1_1.
l f Revi5edJ^jge.1_gf j .
-(Deleted; Original
^ - -[ Formatted: Superscript
RIDER RTP Experimental Real Time Pricing Rider
AVAILABILITY:
This Rider is not available to customers during the period the customer takes electric generation service from a certified supplier. This Rider is not available to customers during the period the customer is taking service under Rider ELR or Rider CPP.
The Experimental Real Time Pricing Rider (RTP) shall be applied in lieu of the Generation Service Rider (GEN) to customers participating in this voluntary experimental program.
PROGRAM DESCRIPTION:
I The RTP Program is voluntary and will be offered on an experimental basis through May31,^014,_unless eariier temninated by the Company. Its purpose is to test customer response to hourly price signals
1 quoted by PJM Interconnection. L.L.C. ("PJM") or any other applicable independent system operatoLto supply electricity. Participation in the RTP Program offers customers the opportunity to manage their electric costs by either shifting load from higher price to lower price periods or by adding new load during lovL er price periods.
' i Deleted: 2011
Deleted: the Midwest Independent Transmission System Operator, Inc. CMidwest ISO")
RATE:
In addition to any other charges under all other rate schedules applicable to customer's service, exclusive of Rider GEN, customers taking service under this Rider shall also pay the charges set forth below:
Charges:
program Administrative Charge: $150.00 per month
RTP Billing:
Customers taking service under this Riderwili be billed based on the following calculation:
RTP Bill = Program Charge + RTP Energy Charge + RTP Fixed Charge + All Applicable Riders
in Case No., before
{ Deleted;
,'{Deleted:
January 20.2010
09-541-EL-ATA / /1 Deleted: Richard R. Grigg
!' ' \ Pfilfited; Febnjary
Issued by:
Filed pursuant to Order dated,
The Public Utilities Commission of Ohio
, President '_ EJTectiye: ^une 1.^011,'
'i "
' ( "/ J '0
'It
{ Deleted: 2010
Ohio Edison Company
Akron, Ohio P.U.C.O. No. 11
iShe_et_l1_1.
1ilBeyi§gd-Pj9Q-^ Qf j .
, - -{Deleted; Original
, - - -( Formatted: Superscript
RIDER RTP Experimental Real Time Pricing Rider
RTP Energy Charge:
The RTP Energy Charge (RTPEC) is equal to the customers houriy energy usage applied to the hourly energy price quotes made publicly available bv-PJM. as defined in the LMPLdefinition,bejo_w.
The RTPEC is calculated as follows:
RTPEC = 2 (kWh, x LMP,)
- - - fpeleted: Midwest ISO
Where:
kWht = Customer's kilowatt-hour usage in hour t t = An hour in the billing period n = Total number of hours in the billing period LMPt = the "Day-Ahead" Locational Marginal Price, or "LMP" in hour t as defined and
specified byJ^JM at the appropriate priciric[nQda as this node may be ch_anged_or_ superseded from time to time byj^JM. I.n_the evejnt tTiereJs an_error ]n_the LMP reported by£J]yij_the CQmpany_shatl agpjy_such prices_as corrected j ^ / J M in monthly bitlings.
The Company shall not be responsible for failure of the customer to receive and act upon market based quotes. The customer is responsible for its access to the Internet for access to£JM pricing.
RTP Fixed Charges:
The following RTP Fixed Charges will apply, by rate schedule, for all kWhs per kWh:
Deleted: the Midwest ISO
Deleted: Commercial Pricing Node labeled "FESR"
Deleted: the Midwest ISO
Deleted: ttie Midwest ISO
Deleted: the Midwest ISO
Deleted: Midwest ISO
Summer Winter
GS
GP
GSU
GT
^ >0QOCj5 •X.xxxxti ^ . . - - j Deleted: 3.3530
.X.xxxxii xxxxxtf ' i Deleted; 2.8734
^ o ^ a ^ jc.xxxx^ ^^^v"i Deleted; 3.0911 ^go«X0 XXXXXtf ^ .. f Deleted: 2.6490
For billing purposes, the winter rates shall be applicable beginning with service rendered September 1 through service rendered for May 31. The summer rates shall apply in all other billing periods.
The customer must arrange for interval metering consistent with the Company's Miscellaneous Charges, Tariff Sheet 75.
TERMS AND CONDITIONS:
Failure by the customer to timely pay all amounts due within thirty (30) days of when due may be cause for removal from service under this Rider, at the option of the Cohipany.
A customer may terminate service under this Rider effective with the next scheduled meter reading following at least 12 days notice to the Company by the customer. Customers who withdraw or are removed from the RTP Program may not return to the RTP Program.
Filed pursuant to Order dated January 20,2010, in Case No. 09-541-EL-ATA, before
The Public Utilities Commission of Ohio
Issued by. Richard R. Grigg, Presidenl Effective: Febmary 1,2010
The Cleveland Electric liiuminating Company
Cleveland, Ohio
' " T Deleted: Original
P.U.C.O. No. 13
^he_etl1_1.
llBeviggdLP_age_ 1_ of 3_ , - - -[ Formatted: Superscript
RIDER RTP Experimental Real Time Pricing Rider
AVAILABILITY:
This Rider is not available to customers during the period the customer takes electric generation service from a certified supplier. This Rider is not available lo customers during the period the customer is taking service under Rider ELR or Rider CPP.
The Experimental Real Time Pridng Rider (RTP) shall be applied in lieu of the Generation Service Rider (GEN) to customers participating in this voluntary experimental program.
PROGRAM DESCRIPTION:
The RTP Program is voluntary and will be offered on an experimental basis through May 31,.^014,_un!ess _^ , - -(Deleted; 2011 earlier tenninated by the Company. Its purpose is lo test customer response to hourly price signals quoted by PJM Interconnection, L.L.C. rPJM"} or any other appiicabte independent system operatOLto , , - -{ Deleted; me supply electricity. Participation in the RTP Program offers customers the opportunity to manage their ~" ^ ' electric costs by either shifting load from higher price to lower price periods or by adding new load during lower price periods.
Deleted: Midwest independent Transmission System Operator, Inc. ('Midwest ISO")
RATE:
In addition to any other charges under all other rate schedules applicable to customer's service, exclusive of Rider GEN, customers taking service under this Rider shall also pay the charges set forth beiow:
Charges:
Program Administrative Charge: $150.00 per month
RTP Billina:
Customers taking service under this Riderwili be billed based on the following calculation:
RTP BiU ^ Program Charge + RTP Energy Charge ••• RTP Fbted Charge + All Applicable Riders
inpase_No^^ before
\ Deleted; Jemuary 20.2010
i\{ Deleted: 09-541-EL-ATA
' 'f ';'.{. Deleted; Richard R. Grigg
Deleted: Febaiary
Issued by:
Filed pursuant to Order dated,
The Public Utilities Commission of Ohio
' , President ^Effediye: June 1.^011 *
I' / / 1 Deleted! 2010 f ' 1 /
• i ' I t J " t
lit it
it
The Cleveland Electric Illuminating Company
Cleveland, Ohio P.U.C.O. No. 13
iShe_et1J_1_
JtlBgyisglPage 2 qf_3
- -TDeleted; Original
- - -{Formatted: Superscript
RIDER RTP Experimental Real Time Pricing Rider
RTP Energy Charoe:
The RTP Energy Charge (RTPEC) is equal to the customers houriy energy usage applied to the hourly energy price quotes made publicly available bvPJM._as defined jn_the LMP.^definition bejoy^^
The RTPEC is calculated as follows:
RTPEC = i:(kWhtX LMP,) 1*1
. ' - { Deleted: Midwest ISO
Where:
kWh, = Customer's kilowatt-hour usage in hour t t = An hour in the billing period n = Total number of hours in the billing period LIMPt = the "Day-Ahead" Locational Marginal Price, or "LMP" in hour t as defined and
specified bvPJM at the appropriate pricino node, as this jiode mav be changed or , -superseded from time to time bvPJM. [njhe event therejs an error jn jhe LMP_ 13"" " -reported bvPJM^ the Company^sjialJ appjy'such prices as corrected bvPJM in _ _ ~ *• v monthly billings. " " ' ""^v ^-.
\ The Company shall not be responsible for failure of the customer to receive and act upon market v based quotes. The customer is responsible for its access lo the Internet for access to j \ IM pricing. "" •- ^
RTP Fixed Charges:
The following RTP Fixed Charges will apply, I3y rate schedule, for all kWhs per kWh:
Deleted: the Midwest ISO
Deleted: Commercial Pncing Node labeled "FESR"
Deleted: the Midwest ISO
Deleted; the Midwest ISO
Deleted: Ihe Midwest ISO
Deleted: Midwest ISO
Summer Winter
GS
GP
GSU
GT
X-xxxxi ^.xxxxft ^.xxxx^ ^-xxxxci
JC.XXXX(i j(.XXXXj
xxxxxtf jC.XXXXtf
- - [ Deleted: 3.3530
Deleted: 2.8734
Deleted; 3.0911
For billing purposes, the winter rates shall be applicable beginning with service rendered through service rendered for May 31. The summer rates shail apply in all other billing periods
"^^^^f Deleted: 2.6490
* \ ^ i Deleted: 2.S919 September 1 >% V « , ^ ^ « , ^ ^ iods. . v j Deleted; 2.4783
> t Deleted: 2.68U
] Deleted; 2.4693
in Case No. before
Issued by: ^
Filed pursuant to Order dated,
The Public Utilities Commission of Ohio
' President Effective
.{ Deleted: January 20.2010
Deleted; 09-541-EL-ATA
Deleted! RichanJ R. Grigg
Deleted: February
Deleted; 2010
June 1..2011/
The Cleveland Electric Illuminating Company Original Sheet 111
Cleveland, Ohio P.U.C.O. No. 13 Page 3 of 3
RIDER RTP Experimental Real Time Pricing Rider
METERING:
The customer must arrange for interval metering consistent with the Company's Miscellaneous Charges, Tariff Sheet 75.
TERMS AND CONDITIONS:
Failure by the customer to timely pay all amounts due within thirty (30) days of when due may be cause for removal from service under this Rider, at the option of the Company.
A customer may tenninate service under this Rider effective with the next scheduled meter reading following at least 12 days notice to the Company by the customer. Customers who withdraw or are removed from the RTP Program may not return to the RTP Program.
Filed pursuant to Order dated January 20, 2010, in Case No. 09-541-EL-ATA, before
The Public Utilities Commission of Ohio
Issued by: Richard R. Grigg, President Effective: Febnjary 1,2010
The Toledo Edison Company
Toledo, Ohio P.U.C.O. No. 8
^heet 116
i f Revised Page 1 of 5
Deletsed: Original
RiDER EDR
Economic Development Rider
a. Residential Non-Standard Credit Provision
APPLICABILITY: Applicable to residential customers taking service under the Company's rate schedule RS to which the Company's Residential Distribution Credit Rider (RDC) applies. This Residential Non-Standard Credit Provision is not applied to customers during the period the customer takes electric generation service from a certified supplier.
RATE: The following Residential Non-Standard credits are effective for service rendered beginning September 1, 2009, for all kWhs per kWh in excess of 500 kWhs per month which are consumed by the customer during the winter billing periods as defined in the Electric Sen/ice Regulations:
APPLICABILITY: Applicable to all customers who look service under PUCO-approved contracts containing interruptible provisions as of February 1,2008 and continue to take service based upog the Company's^ate schedules GP,C3SU, or C3T in conjunction with the Company's Economic Load Response Program Rider (ELR). th is interruptibJe Credit Provision is not applied to custonfie^^ customer takes electric generation service from a certified suppiier.
RATE: The following interruptible credits will apply, by rale schedule, effective for service rendered beginning June 1, ,201Lby unit of Curtailable Load, as defined in Rider
GP (per kW) $ (5.000)
GSU (per k\N) $ (5000)
GT (per IcW) $ (5.000)
{Deleted; unde
1 Deleted: R
[oelebediS 1 1
(Deleted: 2009 1 [ Deleted: B.D5D
1 Deleted: 6.050 |
( Deleted: B.050 1 I
Filed pursuant to Order dated. _ , in Case Nq.,_
The Public Utifities Commission of Ohio
Issued by:, , President
before
Effedive: June1,;^Dll
Deleted: May 27,2009
0G-935-EL-SSO ef al.
Deleted: Richard R. Grigg
12009
The Toledo Edison Company
Toledo, Ohio P.U.C.O. No. 8
Sheet 116
^ L Revised Page 2 of 5
RIDER EDR Economic Development Rider
f^mwrttedt Superscript
c. Non Residential Credit Provision
APPLICABILITY: Applicable to any customer taking General Ser ice - Transmission fGTl. Streel Lightino fSTL), Traffi; Liqhtinj (TRF'i. and Fnvste Outdoor Lighting (POL] service under the Company's rate schedules. This Non-Residential Credit Provision is not applied during the period a customer takes electric generation service from a certified supplier.
RATE: The following credits will apply, by rate schedule, effective for service rendered beginning June 1, 2009, for all kWhs, perkWh:
GT
STL
TRF
POL
Q<.xxx^0
(3.9000)0
(2.4000)^
(0.1495)0
Deleted! 0
Deleted! 178B
d. General Service - Transmission (Rate GJ\ Provision
APPLICABILITY: Applicable to any customer taking servrce under the Company's General Service - Transmission (Rate GT). This provision is not avoidable for customers who take electric generation service from a certified supplier.
RATE: The following charge will apply, effective for service rendered beginning June 1, 2009:
GT {per kVA of billing demand) $ 8.000
The following credit will apply, effective for service rendered beginning January 1, 2010:
GT {all kWhs. per kWh) (x-xxxxM
ADDITIONAL PROVISION: Jhe charges provided for by Section (d) of this Rider shall be applied to the greater of (i) the measured monthly on-peak demand, or(li) 25% of the measured monthly off-peak demand. Monthly on-peak demand is defined as the highest thirty (30) minute integrated kVA between the hours of 6:00 a.m. to 10:00 p.m. EST(eouivalentto 7:00 am, to 11:00 D.m. EDT). Monday through Friday, excluding holidays. Holidays are defined as New Year's Day, Memorial Day, Independence Day, Labor Day, Thanksgiving Day, and Christmas Day. Monthly off-peak demand is defined as the highest thirty (30) minute integrated kVA for all other hours. This provision of Rider EDR is jeconciled within this subpart (d\ quarterly and is revenue neutral to the Companies.
: 1
7724
Deleted The appUcatbn of this { Provision may not resuR in diarges i from ttie Con^ny that are less than zero.
APPLICABILITY: Applicable to any customer that takes electric service under the Company's rate schedules. This Standanj Charge Provision is not avoidable for customers who take electric generation service from a certified supplier.
PURPOSE: The charges provided for by Section (e) of this Rider recover the difference in revenues resulting from the application of rates in the othenAfise applicable rate schedule, and the application of credits in sections (a), (b), (c), and (f), of this Ridet f Deleted: and ce i i ^ other
' generafion credit as ^roved by the RATE: [Commis^on The following charges will apply, by rate schedule for all kWhs per kWh:
Deleled{5882
GS jK-xxxjgii
GP xxxxyjt [Deleted: 5882
f. School Credit Provision
APPLICABILITY: Applicable to any public school district building that either; 1) was served under the Company's Energy for Education II program on December 31, 2008, or 2) is a new public school district building in a school district served under the Company's Energy for Education il program on December 31, 2008 of which fifty-percent (50%) or more of the total square footage of such building is used for classroom-related purposes including any such building that is a mobile unit or temporary structure. This School Credit Provision is not applied to customers during the period the customer takes electric generation service from a certified supplier.
RATE: All applicable charges specified in Company's Generation Service Rider (GEN) for General Service -Secondary ("Rate GS"), General Service Primary ("GP"), or General Service - Subtransmission ("GSU") rates, shall be reduced by 8.693 percenL
Filed pursuant to Order dated, , in Case No., , be^re
The Public Utilitties Commissron of Ohio
Issued by:. , President
The Toledo Edison Company
Toledo, Ohio P.U.C.O. No. 8
Original Sheet 116
Page 4 of 5
RIDER EDR E c o n o m i c Deve lopmen t Rider
q. In f ras t ruc tu re I m D r o v e m e n t p r o v i s i o n .
A F P L I C A S i L i r f :
Appiicabie to any customer that takes electric ser\'ice under the Company's rate schedules with the exception of Street Lighting (STL). Traffic Liohtinq (TRF). and Private Outdoor Lighting fPOL), This jr.frastructLire irrinrov'ementProvision j s no lavo idsb le fo rcus lomers who take electric generation _ service from a certified suppiier. Charges will be allocated in the same manner as the revenue was aiiocate;! in the Company's last distribution rate case, with the exception that no charges are a!ioG8tecj to the STL. TRF and POL schedules.
l! Special Economic • DOTetooment Chame
f Formatted: Bullets and Nuffrtiering )
Peleted! For Ctevaland Clinic i
Deleted! Special Ec(Hioifflc ISevdopment Oiarge
Dueled! For Cleveland Clinic
PURPOSE: The charges providsd for by Section ^q) of this Rider recover costs associated with certain economic exoanst^p. snd new employment in Ohio,
RATE:
The folfovt'inq chs-aes wil! aopiy by rate schedule for all kWhs per kWh:
RS
GS
GP
GSU
GT
X.XXXX^
X.XXXX(t
x.xxxxii
x.xxxxi
x.xxxxi
h. Au tomake r Credi t P rov i s ion
APPLICABIL ITY:
Applicabie to domestic automaker faciiities with mare than AS million kilowatt-hours of consumption for the 12 monthly billing periods ended December 3 1 . 2009_at a single site. This Automaker Credit Pioylsion is gv3il3bi6.for customers who take electric generation service from a certified supplier.
RATE:
Aii credits included in Section fi) of this Rider are appi jed only to usage thai, exceeds the average of the cus lomers twelve (12) biliing periods ended December 3 1 . 2009 ("Baseline Usage").
First 20 percent of k'vVh's over Baseline Usage, per kWh n-aoooci Al l kWh's exceeding 2 0 % over Baseline Usage, per kWh :i .2000)0
Filed pursuant to Order dated , in Case No.
The Public Utilities Commission of Ohio
, before
Issued by:,__
Deleted! H H <#>Resktentiai Non-Standaid Chflwft Pwwlsiofrtt H APPUCABIUTYiH Appicatile to any customer that takes elecbic senftce under the Coir^Kiny's rate sdwAdes fisted in ttiis prowsion with the excepyon of tiiose customei^ who r«eiva tiie ResktenSal Distribution Credit Rider (RDC). This Restdtfitial Non-Standard Charge Piot^lon Is not avcridatrie for customers who take ^ectric ganarafon ssnice ftiOTi a certffied suppiier.1l
PtWPOSE:1t The charges pnnrided for by Action (h) of tti'iB F^der recoww ttie difference in rewmuea resting horn the application dt rates in the ofliemise apjilicable rate sdwdule, and the apjiGcation cf cfedits m secltcm (a) of this Rider.f H RAHiH The following diaiges wtl apply, by rate schedule fbrafi kWhs perkWh^
f RS. X jocxx^ GS-XJOOOC^ GP.xjootx^ FotmatlBcl! Bullets and Numbering
Fbmuttad: Font Not Bold, No underflne
{Deleteitefl
Deleted: not avoidable
DeAetacfe Next 10 peresent of kWh's over Baseliite tJsage, p«-kyvh. (1.0000)^
APPLiCABILiTY: Appiicable ta any custamer that takes electric service under the Company's rate schedules with the exception of Genera! Ser/ice - Transmission (GT). Street Liohtinq fSTLl. Traffic Lighting fTRF), and Private Outdoor Liohtino (POL). This Automaker Charoe Provision is not avoidable for customers v-'ho take electric oensraiion service from a certified supplier.
PURPOSE: The charges provided for bv Section fl) of this Rider recover costs assodated with implementation of the Automaker Credit Prevision.
RATE: The toliov>'inq chiarge wjil apply effective for sen.'ice rendered beginning June 1. 2011. for all i<:Whs per kWh:
Automaker Charge - x.xxxx^
RIDER UPDATES:
The charges contained in this Rider shall be updated and reconciled on a quarterly basis. No later than December 1st, March 1st, June Is land September 1st of each year, the Company will file with the PUCO a request for approval of the Rider charges which, unless otherwise ordered by the PUCO, shall become effective on a service rendered basis on January 1st, April IsL July 1st and October 1st of each year, -beginning with October 1,2011. After Usv 31. 2014. this Rider shall be used for reconcitiatipnpunposes . - (Deletecfe2(^ oniv.
{ Deleted: Richanj R. Gr^g
Filed pursuant to OnJer dated , in Case No. , before
APPLICABILITY: Applicable lo residential customers taking service under the Company's rate schedule RS to which the Company's Residential Distribution Credit Rider (RDC) applies. This Residential Non-Standard Credit Provision is not applied to customers during the period the customer takes electric generation service from a certified supplier.
RATE: The following Residential Non-Standard credits are effectwe for service rendered beginning September 1, 2009, for all kWhs per kWh in excess of 500 kWhs per month which are consumed by the customer during the winter billing periods as defined in the Electric Service Regulations:
Customer rate schedule as of December 31. 2008 "Special Provisions" of Residential Standard Rate Schedule (Original Sheet No. 10) Residential Space Heating Rate (Original Sheet No. 11) Residential Optional Time-of-Day (Original Sheet No. 12) Residential Optional Controlled Service Rider (Original Sheet No. 14) Residential Load Management Rate (Original Sheet No. 17) Residential Water Heating Sen/Ice (Original Sheet No. 18) Residential Optional Electrically Heated Apartment Rate (Original Sheet No. 19)
APPLICABILITY: Applicable to all customers who took service under the Company's interruptible tariffs set forth betow as of February 1, 2008 and continue to take serviceijased upon the Company's rate schedules GP, GSU, or GT in conjunction with the Company's Economic Load Response Pr^rar i i Rider (ELR). This Interruptible Credit Provision is not applied to customers during the period the customer takes electric generation service from a certified supplier.
Interruptible Electric An: Furnace Rate Internjptible Rider - General Service Large and High Use Manufacturing Interruptible Rider - Metal Melting Load Interruptible Rider- Incremental Interruptible Sen/ice
Original Sheet No. 29 Original Sheet No. 73 Original Sheet No. 74 Original Sheet No. 75
fpeleted: under
RATE: The following interruptible credits will apply, by rate schedule, effecth^e for service rendered beginning June 1,,^0lxby unit of Curtailatjie Load, as defined in Ridei-EL^^
GP(perkVV) $(£.00C)
GSU(perkW) $ (5-000)
GT{perkW) $ (5.000)
DelelBd: 2009
8.050
1:8.050
Deleted: 8.050
in Case No.^ before Filed pursuant to Order dated,
The Public Utilities Commission of Ohio
Issuedby:, .President Effective: June 1.^011
May 27,2009
Deleted: 08-935-EL-SSO et at ==^
Deleted: Richard R. Grigg
E}eleted:20ag 5
Ohio Edison Company
Akron, Ohio P.U.C.O. No. 11
Sheet 116
^ ^ Revised Page.2 of 5
RIDER EDR Economic Development Rider
Deleted: 2"
Fonnatted: Superscript
c. Non Residential Credit Provision
APPLICABILITY: Applicable to any customer taking General Service - Transmission (GT'i. Street Liohtinq (STL) and T rs f i ; i!3ht:-!c :TRF) service under the Company's rate schedules. This Non-Reskiential Credit Provision is not applied during the period a customer lakes electric generation service from a certified supplier.
RATE: The following credits will apply, by rate schedule, effective for service rendered beginning June 1, 2009, for all kWhs, per kWh:
GT fx.xxxx^C
STL
TRF
(3.9000)0 (2.4000)0
d. General Service - Transmission fRate GT) Provision
APPLICABILITY: Applicable to any customer taking service under the Company's General Sen/ice - Transmission (Rate GT). This provision is not avoidable for customers who take electric generation service fnsm a certified supplier.
RATE: The following charge will apply, effective for service rendered beginning June 1, 2009:
GT (per kVA of billing demand) $ 8.000
The following credit will apply, effective for service rendered beqinninqjune 1.
GT (all kVWre, perkWh) (x^xxxx)^
ADDITIONAL PROVISION: Xhe charges provided for by Section (d) of this Rider shall be applied to the greater of (i) the measured monthly on-peak demarid, or (11)25% of the measure^^ Monttiiy on-peak demand is defined as the highest thirty (30) minute integrated kVA t)etween the hours of 6:00 a.m. to 10:00 p.m. EST(equivalent to 7:00 a.m. to 11:00 p.m. EDT), Monday through Friday, excluding holidays. Holidays are defined as New Year's Day, Memorial Day, Independence Day, Labor Day, Thanksgiving Day, and Christmas Day. Monthly off-peak demand is defined as the highest thirty (30) minute integrated kVAfor all other hours. This provision of Rider EDR is jeconciled within this subpart (d) quarterly and is revenue neutral to the Companies.
Dieted: Janu^
Deleted! 2010
S=T Detetedi 7724
Deleted: The ai dicatiDn of this Pnsvision may not refill in chafes from the CampsHiy that are less than 2sero. T
Deleted: seff-
Filed pursuant to Order dated. , in Case No..
Tiie Public Utilities Comnrisston of Ohio
Issued by: ^ , President
, before
Effective: June 1.2011
!G«leted! May 27,2Q09
1 Deleted: 08-935-EL-SSO etal.
Deletsd: Rt^iard R Grigg
Deleted: January
!:2010
Ohio Edison Company
Akron, Ohio P.U.C.O. No. 11
Sheet 116
,-^Reyised Page 3 of 5 •.3"
RIDER EDR Economic Development Rider
{Fomiatted; Superscript
e. Standard Charge Provision
APPLICABILITY: Applicable to any customer that takes electric service under the Company's rate schedules. This Standard Charge Provision is not avoidable for customers who take electric generation service from a certified supplier.
PURPOSE: The charges provided for by Section (e) of this Rider recover the difference in revenues resulting from the application of rates in the othenvise applicable rale schedule, and the application of credits in sections (a), (b), (c), and (f) of this Ridei;
RATE: The following charges wilt apply, by rate schedule for all kWhs per kWh:
I Delefeedi and certain o t i ^ genra'atiDn oedits as approved by the
! Commission
GS
GP O.xxxxiife (DelcaiBdi 6Ke
Detebed: 4960
f. School Credit Provision
APPLICABILITY: Applicable to any public school district building that either: 1) was served under the Company's Energy for Education It program on December 31, 2008, or 2) is a new public school district building in a school district served under the Company's Energy for Education II program on December 31, 2008 of which ftfty-percent (50%) or more of the total square footage of such building is used for classroom-related purposes including any such building that is a mobile unit or temporary structure. This School Credit Provision is not applied to customers during the period the customer takes electric generation service from a certified supplier.
RATE: All applicable charges specified in Company's Generation Service Rider (GEN) for General Service -Secondary ("Rate GS"), General Service Primary ("GP"), or General Senrice - Subtransmission ("GSU") rates, shall be reduced by 8.693 percent
: March 3,2010
Deleted: 10-176-CL-ATA
Rk^rd R. Grigg
Man^
:7
2010
in Case No.. before Filed pursuit lo Order dated,
The Public Utilities Commission of Ohio
Issued bv:. .Presjdent Effective: June 12011
Ohio Edison Company
Akron, Ohio P.U.C.O. No. 11
Original Sheet 116
Page 4 of 5
RIDER EDR E c o n o m i c D e v e l o p m e n t Rider
g . in f ras t ruc tu re in?prov6mentPr<7Vis ion.
APPLICABILITY:
Applicable to any customer that takes electric service under the Company's rate schedules with the exception of Street Lighting fSTL), Traffic Lighting (TRFK and Private Outdoor Liohtinq (POL). This Infrastructure ImprovementProvision Js not avoidable for customers who laKe electric oeneration service from a certified supplier. Charoes will be allocated in the same manner as the revenue was allocated in the Company^s last distribution rate case, with the exceptipn that no charges are aliocated to the STL. TRF and POL schedules.
PURPOSE^
The chaross provided for by Section (g) of this Rider recover costs associated with certain economic expansion and nev. employment in Ohio.
RATE:
Ths follov.'ino chsroes wil! apply, bv rate schedule for all kWhs per kWh:
RS x-xxxx i
GS
GP
GSU
GT
X.XXXX^
x.xxxxi x.xxxxc*.
X.XXXX^
h. Au tomaker Credi t P rov i s ion
APPLtCABlL ITY: Appiicsbie to domestic autamakerfai: ities with more than 45 million kilowatt-hours of consumption for the 12 monthly billina periods ended December 3 1 , 2O09.at a single site. This Automaker Credit Provision is .available, for customers who take electric generation service from a certified supplier.
RATE:
Al! credits included in Section (i) of this Rider are appiied oniv to usage that exceeds the average of the customers twelve i12 i biliinQ periods ended December 3 1 , 2009 ("Baseline Usage").
First 2D percent of kWh's over Baseline Usaoe, per kWh (I.QDOOXt
yAlLkWh's exoeedina 20% over Baseline Usage, per kWh n-2000>ci
Issued by:
Filed pursuant to Order dated , in Case No.
The Public Utilities Commission of Ohio
, President
.. before
l! Sneeial Economk: Devetopment Ctiaroe
Formatted: B u l l ^ aKi Numbering )
Deleted; For Ctevatond CHnlc
Delefeed: Speoal Economic Devtiqiment Charge
Ddeted: FOT Cleveland ainic
I: Indent Left 0"
<g>RMfclMirH«l Non-SlandanI Charoe PffOtfislQiill
BESusumjim Applicable to snycustonWT that takes t electricseivice underlie Company's rate st^redt^s listed in tfiis pmwskin with ate exopSon of those customers who receive the Residwitial t^stributianCradft Rider (RDC). This Reslder^t NoivStandard Charge Prowskm is not avoidable for oistem^s who td(e electric generdion service from a certified supplier.1l
PURPQSE.it The c^rges |»x>vided Ibr by SeCHon (h) aS this f € ^ recover the difference in revenues resirtfing fnwn the appEcafion of rales in the ottieniirise appBcable rate schedule, and the appBcaOon of credits in section (a) of this Rider.H
BATgUI The foHowing targes wiH apply, by ratesdieduleforaHkWhsperlf ,J[^j-]
Formatted: Not Highlight
FbnnattBd; f i l e t s and Numbering
:S|aceAfter: 3pt
Deleted: 1
Next 10 percent c^ kWh's over Bas^ne lisags, per ,J2l Fbrmalted: Indent: Left: 0"
APPLiCABtLJTY: Appiicable to any customer that takes electric service under the Companv's rate schedules with the exception of Genera! Service - Transnission (GT). Street Lighting (STL). TrgfTic Lighting (TRF), and Private 0 jtdopr Lighting (POD- This Auton^aker Charge Provision is not avoidabie for customers v/ho take eiectric: oeneration service from g certified suppiier.
PURPOSE: The charges pro\'ided for bv Section (ii of this Rider recover costs associated with implementation of the Autori^sker Credit Provision.
RATE: The foliovvina, charge wilt appiy effective for service rendered t>eQ!nninQ June 1, 2011. for ail kWhs per kWh;
Indent: Left: 0"
Autornsker Charge X.XXXX C
RIDER UPDATES:
The charges contained in this Rider shall be updated and reconciled on a quarterly basis. No later than December 1st, March 1st, June 1st and September 1st of each year, the Company will file with the PUCO a request for approval of the Rider charges which, unless otherwise ordered by the PUCO, shall become effective on a service rendered basis on January 1st, ApriUst, July 1st and October 1st of each year, beginning October 1.^011. After Mav 31. 2014. this Rider shall be used for reconciliation purposes only.
Fonnatted:Spa(£After; Opt
Formatted: Nomat, Indent: Left: 0", Space After: 0 tA, Tabs: Not at 5.r
Deleted: 2009
Richard R. Grigg
Filed pursuant to Order dated , In Case No. ., before
APPLiCABILiTY: Applicable to any customer that takes eiectric service under the Company's rate schedules listed in this provision with the exception of those customers who receive the Residential Distribution Credit Rider (RDC). This Residential Non-Standard Charge Provision is not avoidable for customers who take electric generation service from a certified suppiier.
PURPOSE: The charges provided for by Section (h) of this Rider recover the difference in revenues resulting from the application of rates in the otherwise applicable rate schedule, and the application of credits in section (a) of this Rider.
RATE: The following charges will apply, by rate schedule for all kWhs per kWh:
RS x.xxxx5i
GS x.xxxx^
GP X.XXXX0
Page 4: [2] Deleted Useilillame 3/23/2010 3:03:00 PM Next 10 percent of kWh's over Baseline Usage, per kWh (1.0000)(i
The Cleveland Electric Illuminating Company
Cleveland, Ohio P.U.C.O. No. 13
jSheet 116
i f Revised Paget of 5
Deleted: Ordinal
RIDER EDR Economic Developmer^t Rider
a. Residential Non-Standard Credit Provision
APPLICABILITY: Applicable to residential customers taking service under the Company's rate schedule RS to which the Company's Residential Distribution Credit Rider (RDC) applies. This Residential Non-Standard Credit Provision is not applied to customers during the period the customer takes electric generation service from a certified supplier.
RATE: The following Residential Non-Standard credits are effective for service rendered beginning September 1, 2009, for all kWhs per kWh in excess of 500 kWhs per month which are consumed by the customer during the winter billing periods as defined in the Electric Service Regulations:
Customer rate schedule as of December 31. 2008 "Optional Load Management" section of Residential Standard {Original Sheet No. 10) (1.9000)0 Residential Add-On Heat Pump (Original Sheet No. 11) (1.9000)0 Residential Water Heating (Original Sheet No. 12) (0.5000)0 Residential Space Heating (Original Sheet No. 13) (1.9000)0 Residenliai Water Heating and Space Heating (Original Sheet No. 14) (1.9000)0 Optional Electrically Heated Residential Apartment Schedule (Original Sheet No. 15} (1.9000)0
{^wmatted! Superscript
b. interruptible Credit Provision
APPLICABILITY: Applicable to all customers who took sen/ice under PUCO-approved contracts containing interruptible provisions as of February 1,2008 and continue to take servicei^ased upon the Company's rate f schedules GP, GSU, or GT in conjunction with the Company's Economic Load Response [Program Rider (ELR). This Interruptible Credit Provision is not applied to customers during the period the customer takes electric generation service from a certified supplier.
RATE: The following interruptible credits will apply, by rate schedule, effective for service rendered beginning June 1,2011 bv unit of Curtailable Load, as defined in Rider ELR: 1
GP(perkV> -nonlh) $ (5.QQ0)
GSU (perkWirTonir) $ (3.QQ0>
GT (per kW/rnontn) $05 000) ^
Deleted: under
Deleted: 2009
Deleted: a.DSO
Filed pursuant to Order dsfted, , in Case No., tiefore
j Issued by; ^
The Public Utilities Commission of Ohio
Presidenl Effective: June 1,2011
DdelBd:nilay27,2Q09
DB^35-EL-SS0etal
Ricshard R. Grigg
2D09
The Cleveland Electric llluminatir^ Company
Cleveland, Ohio P.U.C.O. No. 13
Sheet 118
ailRwjsed Page? of 5
RIDER EDR Economic Development Rider
Deleted: 2'^
fonnatted; Superscript
c. Non-Residential Credit Provision
APPLICABILITY: Applicable to any customer taking Gsr^sral Sewk Transnnission (GT). Street Lightino (STLV Trsffic Li-ohtino (TRF). ana Private Outdoor Liohtinq (POL) service under the Company's rate schedules. This Non-Residential Credit Provision is not applied during the period a customer takes electric generation service from a certified supplier.
RATE: The following credits will apply, by rate schedule, effective for service rendered beginning June 1, 2009, for all kWhs, per kWh:
GT (X.XXXX )ri
STL
TRF
POL
(4.4737)0
(4.1555)0
(2.2764)0
d. General Service • Transmission (Rate GT) Provision
APPLICABILITY: Applicable to any customer taking service under the Company's General Service - Transmission (Rate GT). This provision is not avoidable for customers who lake electric generation service from a certified supplier.
RATE: The following charge will apply, effective for service rendered beginning June 1, 2009;
GT (par kVA of billing demand) $ 8.000
The following credit will apply, effective for service rendered beginning January 1, 2010:
GT(aHkWhs, perkWh) (x.xxxx)0
ADDITIONAL PROVISION: ,The charges provided for by Sectton (d) of this Rider shall be applied to the greater of (i) the measured monthly on-peak demand, or (iO 25% of the measured monfhiy off-peak demand. Month^ on-peak demand is defined as the highest thirty (30) minute integrated kVA between the hours of 6:00 a.m. to 10:00 p.m. ESTfeauivaient to 7:00 a.m. to 11:00 p.m. EDT\. Monday through Friday, excluding holidays. Holidays are defined as New Year's Day, Memorial Day, Independence Day, Labor Day, Thanksgiving Day, and Christmas Day. Monthly off-peak demand Is defined as the highest thirty (30) minute integrated kVA for all other hours. This provision of Rider EDR is jecanciled within this subpart id] quarterly and is revenue neutrai to the Companies.
: 1 »J Deleted: 7724
Ddrted: The applicafion of ^ s Provi on may not t&uA in charges from tiie Con^sny thsd are less Qiat MTO.
Deleted: sel^
Filed pursuant to Order dated. . in Case No..
The Public Utilities Contmission of Ohio
Issued by:. , President
before
Effective: June 1. 011
[Peleted: May 27.2009
Deleted: 0&^35-EL-SSO et at
Delelecfe Ridiard R. Grigg
Peleted; January
Peleted: 2010
The Cleveland Electric Illuminating Company
Cleveland, Ohio P.U.C.O. No. 13
Sheet 116
J "_Revised Page 3 of 5
RIDER EDR Economic Development Rider
j Deleted: 3"*
'iFonnattMfc Superscript
e. Standard Charoe Provision
APPLICABILITY: Applicable to any customer that takes eiectric service under the Company's rate schedules. This Standard Charge Provision is not avoidable for customers who take electric generation service from a certified supplier.
PURPOSE: The charges provided for by Section (e) of this Rider recover the difference in revenues resulting from the application of rates in the othen^/ise applicable rate schedule, and the applk:ation of credits in sections (a), (b), (c) and (f) of this Ridet;
RATE: The following charges will apply, by rate schedule for all kWhs per kWh:
GS
GP
I: and certain other generation cretSts as approved by the Commis^n
Deieted! 0
Deieted: 5B82
:o
f. School Credit Provision
APPLICABILITY: Applicable to any public school district building that either: 1) was served under the Company's Energy for Education II program on December 31, 2008, or 2) is a Cleveland Municipal School District building that was served by the Company on January 21, 2009, or 3) is a new public school district building in the Cleveland Municipal School District or in a school district that was served under the Company's Energy for Education II program on December 31, 2008 of which fifty-percent (50%) or more of the total square footage of such building is used for classroom-related purposes including any such building that is a mobile unit or temporary structure. This School Credit Provision is not applied to customers during the period the customer takes electric generation service from a certified supplier.
RATE: All applicable charges specified in Company's Generation Service Rider (GEN) for General Service -Secondary ("Rate GS"). General Service Primary ("GP"), or General Service - Subtransmission ("GSU") rates, shall be reduced by 8.693 percent.
[ Deleted: 5BK
March 3.2010
: 10-176-EL-ATA
Deleted: Rkihard R. Giigg
M»ch
Deleted:?
Deleted: 2010
Filed pursuant to Order dated _ , in Case No.,_
The Public Utilities Commission of Ohio
issued by : ,_ . President
, before
The Cleveland Electric Illuminating Company
Cleveland, Ohio P.U.C.O. No. 13
Original Sheet 116
Page 4 of 5
RIDER EDR Economic Development Rider
'ementProvision. 0. Infrastrijcture Ir^rsr;
APPyCABlUTY: Acolicabie to any customer that takes electric service under the Companv's rate schedules with the g.xcectJcn of Street LichiinQ /STL). Traf^c LJohtinq (TRF), and Private Outdoor LJohting fPOL). This Infrsstrjcture imcrcvement Provision Js not avoidabie for customers who take eiectric generation senyjce from a csrtifjed suppiier. Charges will be allocated in the same manner as the revenue was -3llcc3t6d In the Ccmpany's iast distribution rate case, with the exception that no charges are aliocated to the STL. TRF and POL schedules.
Deleted; Special Economic
Formatted: billets and Nttfnbering)
Deleted; For Cleveland Clinic
. . SpKia! Economk: I Devetoprnwtf Charge Deleted: For Qsveland Clinic
PURPOSE: The cliarqes creviced for by Section (Q) of this Rider recover costs associated with certain economic expansion and new en-;plcvrnent in Ohio.
RATE: T'ne foiiov inQ c.larges will apply, bv rate schedule for all kWhs per kWh:
RS
GS
GP
GSU
GT
x.xxxxii
x.xxxx;2
x.xxxxij
X.XXXX^
x.xxxxc
h. A'Jtomak&r Credit PTGv<5ion
APPLiCABiLiTY; Appiicable to ccmestic auicmaker faciiities with more than 45 million kilowatt-hours of consumption for the 12 mcnthiv biiling ceriods ended Decemt)er31. 20Q9.at a single site. This Automaker Credit Provisicn :s 3V5i|gb!e.fcr Customers who take electric generation service from a certified supplier
RATE: Ail credits 'nciuded in Section (i) of this Rider are applied oniv to usaoe that exceeds the average of ihe customers ^ve^-e (12) S iiling oeriods ended December 31, 20GS ("Baseiine Usace").
First 2^ cercspi of kVVh's ever Baseline Usage, per KWh n m O O H
M kWh's exceeding 20% ever Baseline Usage, per kWh n.2G0Q)^
Ddeted;f H <#=-Resldential Non-Standard Ch^ijH PKnsfs!ft,il1
ismjsmusm Applicable to any customer ti^at takes , etedricsenivce under the Con' Teny j rate st^Klules Rsted in tfiis provisan vnth tiw exception of those GuskJmers wrtio receive ffie Re^enli^ Dislribution Credit Rkter (ROC) This ResidenSari Non-Standaid Qiarge Proviaon e not avoklatHefor customers vriio take electric generaSon senrice firom a certified suppfier.H
PtJRPOSE.it The i argea provided for by Section (h) of ttiis Rkler recover Ihe diffierence in revenues nssuBing from the appBcation of rates in tt» othenvise appEc rte rate sdiettele, and the applc fein trf credSs In section (a) erf this Rider.H It RATEil Ttie foHotiKng diarges will apply, by rate schedule for all kWhs per kWhif fl RS xjoooc^ GS.XJODOC^ GP x.)(xxxiffl
: Mot hBghlight i ' [ Formattedi Billets and Numbering
Deleted:8
Deleted: notavokJabte
Deleted: 1 Deleted: 0.8
Deleted: Next 10 percent of kWh's over Bas^bte Usage, per kWh (1.0000)^ .
The Cleveland Electric Illuminating Company Original Sheet 116
Cleveland, Ohro _^___ P.U.C.O. No. 13 Page 5 of 5
RIDER EDR Economic Development Rider
j . .Automakgr Cha.'-ge Provision
APPUCASILITY: Acolicabie 'o any cijstomer that takes electric service under the Company's rate schedules with the excsction of General Service - Transmission fGT). Street lighting (STU. Traffic Lighting (TRF). and Private OutcJQcr Lighting (POL}. This Automaker Charge Provision is not avoidable for customers v^ho take etectric csneraticn service from a certified supplier.
PURPOSE-: The charges orovided fcr by Section fi) of this Rider recover costs associated with impiementation of the Automaker Crsdii Provisicn.
RATE: The fcilovvinq charts wilt acolv affective for service rendered tieginning June 1. 2011. for all kWhs per kVVh:
Automsksr Cnarce x.xxxxt
RIDERUPDATES:
The charges contained in this Rider shall be updated and reconciled on a quarterly basis. No later than December 1st, March 1st, June 1st and September 1st of each year, the Company will file with the PUCO a request for approval of the Rider charges which, ur\less otherwise ordered by the PUCO, shall become effective on a service rendered basis on January 1st, April 1st, July 1st and October 1st of each year, tjeginning October 1.201 h After Mav 31. 2014, this Rider shall be used for reconciiiation purposes only. - ( Detetctfe 2QQ9
[ Deleted: Richard R Grigg
Filed pursuant to Order dated , in Case No. . before
The Public Unities Commission of Ohio
Issued by:, __, President Effective: June 1,2Q11
o T H
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3 H E!:
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I 1 ^ (.,1 W
"0
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3§
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H > » ^ Cfl £
BILLING UNIT DATA - 6 MONTHS ACTUAL - 6 MONTHS ESTIMATED TYPE OF PILING: ELECTRIC SKCUWT-? PLAN (ESP)
OHIO EDISON COMPANY CASE NO. 10-XXXX-EL-SSO ESTIMATED RATE IMPACTS
ANNUALIZED RATES @ MAY 2012
SCHEDULE 1 PAGE 2 OF 15
RATE CODE / DESCRIPTION CUSTOMER
BILLS BILLING UNTTS
MAV 2012 PROPOSED
RATES
MAY 2012 PROTOSED
REVENUE
% OF TOTAL REVENUE
i L (B) (Q i2L M. JFl (5) (S)
HESIDENTIAI. SERVICE (RS) - TOTAL
DISTRIBUTION CHARGES
CUSTOMER CHARGE BILLS, PER MONTH
ENERGY CHARGE. PER kWh
GENERATION CAPACITY CHARGES
GENERATION CAPACITY CHARGE, PER kWh
NON-MARKET-BASED SERVICES RIDER (NMB), PER kWh
GENERATION ENERGY CHARGES
ALL SUMMER kWh, PER kWh
FIRST 500 kWh OVER 500 kWh
ALL WINTER fcWh, PER kWh
RIDERS
• S M / ENERGY EPFICIENCY DEMAND SIDE MANAGEMENT AND ENERGY EFFiaENCY (DSEI), PER kWh DEMAND SIDE MANAGEMENT AND ENERGY EFFICIENCY {DSE2), PER kWh
DEMAND SIDE MANAGEMENT (DSMX PERkWh
STATE kWh TAX (SKT) FIRST 2,000 kWh, PER kWh NEXT 13,000 kWh, PER kWh ABOVE 15,000 kWh, PER kWh
RESIDENTIAL DISTRIBUTION CREDIT (RDC). PERkWh
ADVANCED METERING INFRASTRUCTURE / MODERN GRID (AMI), PER kWh
DELTA REVENUE RECOVERY RIDER (DRR), PER kWh
ECONOMIC DEVELOPMENT (EDR) WATER HEATING, PER kWh SPACE HEATING & LOAD MANAGEMENT, PER kWh
DELIVERY CAPITAL RECOVERY (DCR). PER kWh
NON-DISTRIBUTION UNCOLLECTIBLE RIDER (NDU). PER kWh
DISTRIBUTION UNCOLLECTIBLE RIDER (DUN). PER kWh
DEFERRED FUEL COST RECOVERY RIDER (DFC), PER kWh
ALTERNATIVE ENERGY RESOURCE RIDER (AER), PER kWh
GENERATION COST RECONClLLkTION (GCR). PER kWh
USR FIRST 833k kWh, PER kWh OVER 833k kWh, PER kWh
RESIDENTIAL GENERATION CREDIT (RGC), PER kWh
ECONOMIC DEVELOPMENT (EDR) - AUTOMAKER CHARGE PROVISION, PERkWh
ECONOMIC DEVELOPMENT (EDR) - INFRASTRUCTURE IMPROVEMENT PROVISION, PER kWh
BILLING UNIT DATA - 6 MONTHS ACTUAL - 6 MONTHS ESTIMATED TYPE OF FILING: ELECTRIC SECURITY PLAN (ESP)
OHIO EDISON COMPANY CASE NO. 10-XXXX-EL-SSO ESTIMATED RATE IMPACTS
ANNUALIZED RATES @ MAY 2012
SCHEDULE I PAGE3 0 F I 5
RATE CODE / DESCRIPTION
MAY 2012 CUSTOMER PROPOSED
BILLS BILLING UNFTS RATES
MAY 2012 PROPOSED % OF TOTAL REVENUE REVENUE
iAL (B) (C) (D) (E) iEL (5)
GENERAL SERVICE - SECONDARY (GS)
DISTRIBUTION CHARGES
CUSTOMER CHARGE BILLS, PER MONTH
CAPACITY CHARGE UP TO 5 kW OF BILLING DEMAND, PER MONTH OVER 5 kW, PER kW
REACTIVE DEMAND CHARGE ALL rfcVa, PER rkVa
GENERATION CAPACITY CHARGES
GENERATION CAPACITY CHARGE, PER kWh
NON-MARKET BASED SERVICES RIDER (NMB), PER kW
GENERATION ENERGY CHARGES
ALL SUMMERkWh, PERkWh ALL WINTER kWh. PER kWh
RIDERS
DSM / ENERGY EFFIQENCY
DEMAND SIDE MANAGEMENT AND ENERGY EFRCIENCY (DSEI). PER kWh DEMAND SIDE MANAGEMENT AND ENERGY EFRCIENCY (DSE2). PER kWh
STATE kWh TAX (SKI) FIRST 2,000 kWh. PERkWh NEXT 13,000 kWh, PER kWh ABOVE 15,000 kWTi, PER kWh
BUSINESS DISTRIBUTION CREDIT (BDC), PER kWh
ADVANCED METERING INFRASTRUCTURE / MODERN GRID (AMI). PER kWh
DELTA REVENUE RECOVERY RIDER (DRR), PER kWh
ECONOMIC DEVELOPMENT (EDR) STANDARD CHARGE PROVISION, PERkWh SCHOOL CREDIT 8 693% of GENERATION (SUMMER) SCHOOL CREDIT 8.693% of GENERATION (WINTER) SCHOOL CREDIT 8.693% OF CAPACITY
DELIVERY CAPITAL RECOVERY (DCR) UP TO 5 kW OF BILLING DEMAND. PER kW OVER 5 kW, PER kW
OHIO EDISON COMPANY CASE NO. 10-XXXX-EL-SSO ESTIMATED RATE IMPACTS
ANNUALIZED RATES @ MAY 2012
BILLING UNIT DATA - 6 MONTHS ACTUAL - 6 MONTHS ESTtMATEE TYPE OF FILING: ELECTRIC SECURITY PLAN (ESP
SCHEDULE 1 PAGE 4 OF 15
RATE CODE / DESCRIPTION CUSTOMER
BILLS BILLING UNITS
MAV Ml! ' MAV W i PROPOSED PROPOSED % OF TOTAL
RATES REVOWE REVENUE (B) (D) j a . £L (S) <$)
GENERAL SERVICE - PRIMARY (CP)
DISTRIBUTION CHARGES
CUSTOMER CHARGE BILLS, PER MONTH
CAPACITY CHARGE ALL kW OF BILl -ING DEMAND, PER k%
REACTIVE DEM.WD CHARGE ALL ikVa, PER ikVa
TRANSFORMER CHARGE ALL kW OF BU.LING DEMAND, PER kW
GENERATION CAPACITY CHARGES
GENERATION CAPACITY CHARGE, PER kWI
N O N - M A R K E T - B A S E O SERVICES RIDER (NMB), PER kW
GENERATION ENERGY CHARGES
NON TIME OF DAY ALL SUMMER kWh, PER kWl ALL WINTER kWh, PER kWl
TIME OF DAY SUMMERDN-PEAK, PERkWh SUMMER OFF-PEAK WINTER ON-PE-MC WINTER OFF-PEAK
DSM / ENERGY EFTICIENCY DEMAND SIDE MANAGEMENT AND ENERGY EFFICIENCY (DSE 1), PER kWl DEMAND SIDE MANAGF-MENT AND ENERGY EFFICIENCY tDSE2), PER kWI
STATE kWh TAX (SKI) FIRST 2,000 kWh. PER fcWh NEXT 13,000 kWh, PER kWh ABOVE 15,000 kW^ PER kWb
BUSINESS DISTFJBUTION CREDIT (BDC), PER kWl
ADVANCRD METERING INFRASTRUCTURE/ MODERN CBtlD (AMI), PER kWl
DELTA REVENUE RECOVERY FJDER (DRR), PER kWl
ECONOMIC DEVELOPMENT (EDR) ST.-VNDARD CHARGE PROVISION, PER kWl INTERRUPTIBI-E CREDIT PROVISION, PER KVt SCHOOL CREDIT 8.693% of GENERATION (SUMMER) SCHOOL CREDIT 8,69:1% of GENERATION (WINTER) SCHOOL CREDIT 8,693% OF CAPACITY
ECONOMIC LOAD RESPONSE (ELR) INTERRUPTIBI£ PROGRAM ADMINISTRATIVE CHARGE DEMAND CURTAILABLE ENERGY CREDIT, PER KW
DELIVERY CAPITAL RECOVERY (DCR) ALL kW OF en-LING DEMAND, PER k%
NON-DISTRIBUTION UNCOLLECTIBLE RIDER (NDU). PER tWI
DISTRIBUTION imCOLLECTIBLE RIDER (DUN). PER kWl
DEFERRED FUEL COST (DFC), PER kWh
ALTERNATIVE £NERGY RESOURCE RIDER (AER), PER kWl
SCHOOL DISTRIBUTION CREDIT RIDER (8,693%)
GENERATION COST RECONCILIATION (OCR). PER kWl
USR FIRST 835k kWh. PERkWb OVER 83 5k kWh, PER kWh
ECONOMIC DEVELOPMENT (EDR) - AUTOMAKER CHARGE PROVISION PER fcWi
ECONOMIC DEVELOPMENT (EDR) - INFRASTRUCTURE IMPROVEMENT PROVISION, PER fcWl
TOTAL RIDERS
TOTAL PROPOSED - GS - PRIMARY
12.382 2.267.186,074
5,218,688
263,905
2.267.186,074
5,218.688
£150,00 SI,8S7J7P
52,2550 511,763,141
S0.36 $95,006
$000 SO
50.0058 $13,138,343
51,7110 $8,929,175
(%)
6.70
4.33
603.469,748 1,663,716.327
.
-
$0.062165 $0052888
$0.086750 50.040613 50.070416 $0.037429
$37,514,697 $87,990,629
$0 SO so so
19.13 44.86
0.00 0.00 0.00 0.00
-
12.382
2,267.186.074 2.267,186.074
20.824,865 123.006.838
2.067.891,929 2,211,723.632
325,729
2,267,186,074
2,267,186.074
2,267,186,074
25,562,046 88,638,510
136,566
5.218,688
2,267,186,074
2.267,186,074
2.267.186,074
2,267,186,074
114.200,556
1,267,186,074
196139937S 30S736696.S
2,267.186,074
2,267.186,074
2.267.186.074
$0.000686 $0.000465
$0,004660 $0.004200 $0.003640 _
(S0.020000)
$0.000096
50.000000
$0.002292 ($5,000)
($0.005404) (50.004598)
($0.0005)
$150,000 ($5,000)
$0,7010
50,000212
£0.000000
SO000362
£0.00324
(S0.O0O44)
S0.001006
$0,002025 J0.001046
£0.00007
£0.00011
$0.0365
$1,555,290 $1,054442
$97,0U £516.629
$7,327,127 88,140,799
($6,515)
£217,871
$0
£5,196,976 SO
($138 ,137)
(£407 ,520)
($69)
SO
£0
£3 ,658 ,300
£480 ,643
$0
$ 8 2 1 , 0 8 4
$7 ,341 ,149
($50 ,068)
$2 ,280 ,789
S 3 . y r a , 2 2 6
£319 ,883
£160 ,802
$245 ,371
$34 ,843 ,315
$196,136^83
0.79 0.54
0.03 0.26 3.84
(0.00)
0.11
0.00
2.65 0.00 (0.07) (0,21) (0.00)
0,00 0.00
1.87
025
0.00
0.42
3.74
(0.03)
1.16
2.03 0.16
0,08
0.13
17,76
100.00
OHIO EDISON COMPANY CASE NO. 10-XXXX-EL-SSO ESTIMATED RATE IMPACTS
ANNUALIZED RATES @ MAY 2012
BILLING UNIT DATA - 6 MONTHS ACTUAL - 6 MONTHS ESTIMATED TYPE OF FlUNG. ELECTRIC SECURITY PLAN (ESP
SCHHJULEl PAGE 5 OF 15
hikVWl 'MAVW15
RATE CODE / DESCRIPTION CUSTOMER
BILLS BHAING UNITS
% 0 F TOTAL REVBTOE
(B) (D) (E) m GENERAL SERVICE PRIMARY - INTERRUPTIBLE (GP)
DISTRIBUTION CHARGES
CUSTOMER CHARGE BILLS. PER MONTH
CAPACITY CHARGE ALL kW OF BILLING DEMAND, PER kW
REACTIVE DEMAND CHARGE ALLikVa,PERikVa
TRANSFORMER CHARGE ALL kW OF BILLING DEMAND, PER kW
GENERATION CAPACITY CHARGES
GENERATION CAPACITY CHARGE. PER kWV
NON-MARKET-BASED SERVICES RIDER (NMB), PER kW
GENERATION ENERGY CHARGIES
NON TIME OF DAY
ALL SUMMER kWh, PER kWh ALL WINTER kWh, PER kWl
TIME OF DAY SUMMER ON-PEAK, PER kWli SUMMER OFF-PEAK WINTER ON-PEAK WINTER OFF-PEAK
65,109,366
191,787
£150,00
£2,2550
50.36
£0.005
$1-711
$16,200
$432,479
S31
$377,309
$328,147
8.38
7.29
16.392.977 48.716.389
. -. -
$0 062163 $0,052888
10.086750 £0 040613 £0,070416 £0,037429
$1,019,069 $2,576,512
$0 $0 $0 $0
22.64 37.23
0.00 0,00 0.00 0.00
DSM/ENERGY EFFICIENCY DEMAND SIDE MANAGEMENT AND ENERGY EFHCIENCY (DSEI), PER kWl DEMAND SIDE MANAGEMENT AND ENERGY EFFICIENCY (DSE2), PER kWl
STATE kWhTAX (SKT) FIRST 2,000 kWh, PER kWh NEXT 13.00C kWh, PER kWh ABOVE 15.000 kWh. PER kWb
BUSINESS DISTRIBUTION CREDIT (BDC). PER kWl
ADVANCED METERING INFRASTRUCTURE / MODERN GRID (AMI), PER kWl
DELTA REVENUE RECOVERY RIDER (DRR), PER kWl
ECONOMIC DEVELOPMENT (EDR) STANDARD CHARGE PROVISION, PER kWl INTHIRUPTIRLE CREDIT PROVISION. PER KVt SCHOOL CREDIT 8.693% of GENERATION (SUMMER) SCHOOL CREDIT 8.693% of GENERATHW (WINTER) SCHOOL CREDIT 8.693% OF CAPACITY
ECONOMIC LOAD RESPONSE (ELR) INTERRUPTIBLE PROGRAM ADMINISTRATIVE CHARGJ
DEMAND CURTAILABLE ENERGY CREDTT, PER Kft
DELIVERY CAPITAL RECOVERY (DCR; ALL kW OF BILLING DEMAND, PER kft
NON-DISTRIBUTION UNCOLLECTIBLE RIDER (NDU). PER kWI
DISTRIBUTION UNCOLLECTIBLE RIDER (DUN), PER kWl
DEFERRED FUEL COST (DFC), PER kWli
ALTERNATIVE ENERGY RESOURCE RIDER (AER). PER kWl
DELTA REVEMUE - CEI CONTRACT
GENERATION COST RECONCILIATION (GCR), PER kWli
USR FIRST 833k kWh, PER kWh OVER 333k kWh, PER kWh
ECONOMIC DEVELOPMENT (EDR) - AUTOMAKER OIARGE PROVISION, PER kWI
ECONOMIC DEVELOPMENT (EDR) - INFRASTRUCTURE IMPROVEMENT PROVISION, PER kWl
TOTAL RIDERS
TOTAL PROPOSED - GS - PRIMARY
103
108
65.109,366 65,109,366
216.000 1,403,399
63,489,967 65,109:366
-65,109,366
65,109,366
65,109,366 127,086
127,086
191,787
63,109.366
65.109,366
65,109.366
63,109.366
65,109.366
65.109.366
56327740.99 8781625.014
65,109.366
65,109,366
65,109.366
£0000000 £0,000463
$0,004660 £0.004200 £0.003640
(£0.020000)
$0000096
£0.000000
$0.002292 (£5.000)
($0.005404) ($0004598)
$0.0000
$150,000 (55.000)
$07010
$0,000212
$0.000000
$0,000362
$0.00324
#DlV«r
50.001006
£0,002025 $0,001046
$0.00007
$0,00011
$0 0691
$0 $30,276
$1,007 $5,894
$231,103 $238,004
SO
$6,257
SO
$149,247 ($635,431)
SO SO SO
$16,200 ($635,431)
$t34,U2
$13,803
$0
$23,580
$210,824
$0
$65,300
$114,075 $9,186
$4,618
$7,052
(£247.797)
$4,301,949
0.00 0,67
0.02 0.13 5,13
0.00
0,14
0.00
3.32 (14.11) 0.00 0.00 0.00
0.36 (14.11)
2.99
0.31
0.00
0.52
4.68
0.00
1.45
2.53 0.20
0.10
0.16
(5.30)
100.00
OHIO EDISON COMPANY CASE NO. lO-XXXX-EL-SSO ESTIMATED RATE IMPACTS
ANNUALIZED RATES @ MAY 2012
BILLING UNIT DATA - 6 MONTHS ACTUAL - 6 MONTHS ESTIMATEC TYPE OF FR.ING: ELECTRIC S E C U R H Y " PLAN (ESF
SCHEDULE I PAGE 6 OF 15
MAV 5015
RATE CODE / DESCRIPTION CUSTOMER
BILLS BILLING UNTTS MAY 2012 PROPOSED
REVENUE %OF TOTAL
REVKJUE (B) (C) (D) ML i2-
(S)
GENERAL SERVICE - SUBTRANSMISSION (GSU)
DISTRIBUTION CHARGES
CUSTOMER CHARGE BILLS, PER MONffl
CAPACITY CHARGE ALL kW OF BILLING DEMAND, PER kft
REACTIVE DEMAND CHARGE ALLifcVa,PERikVa
TRANSFORMER CHARGE ALL kW OF BILLING DEMAND, ffiR kW
GENERATION CAPACITY CHARGES
GENERATION CAPACITY CHARGE, PER kWl
NON-MARKET-BASED SERVICES RIDER (NMB), PER kW
GENERATION ENERGY CHARGES
ALL SUMMER kWh, PER kWIi ALL WINTER kWB, PER kWl
RIDERS
DSM / ENERGY EFFICIENCY DEMAND SIDE MANAGEMENT AND ENERGY HTICIENCY (DSEI). PER kWl DEMAND SIDE MANAGEMENT AND ENERGY EFFICIENCY (DSE2), PER fcWl
STATE kWh TAX (SKT) FIRST 2,000 kWh. PER kWh NEXT 13,000 kWh, PER kWh ABOVE IS.OOOkWh,PERkWh
BUSINESS DISTRIBUTION CREDIT (BDC). PER kWt
ADVANCED METERING INFRASTRUCTURE /MODERN GRID (AMI). PER kWI
DELTA REVENUE RECOVERY RIDER (DRR), PER kWl
ECONOMIC DEVELOPMENT (EDR) STAN'DARD CHARGE PROVISION, PER kWl INTERRUPTIBLE CREDIT PROVISION. PER Kft SCHOOL CREDIT 8,693% of GENERATION (SUMMER) SCHOOL CREDIT 8.693% of GENERATION (WINTER) SCHOOL CREDIT 8.693% OF CAPACITY
ECONOMIC LOAD RESPONSE (ELR) INTERRUPTIBLE PROGRAM ADMINISTRATIVE CHARGF DEMAND CURTAILABLE ENERGY CREDIT. PER KW
DELIVmiY CAPITAL RECOVERY (PCR] ALL kW OF BILLINO DEMAND. PER kVi,
NON-DISTRIBUTION UNCOLLECTIBLE RIDER (NDU). PER kWI
DISTRIBUTION UNCOLLECTIBLE RIDER (DUN), PER kWl
DEFERRED FUEL COST (DFC), PER kWl
ALTERNATIVE ENERGY RESOURCE RIDER (AER). PER fcWI
SCHOOL DISTRIBUTION CREDIT RIDER (8.693%)
GENERATION COST RECONCILIATION (GCR). PER kWI
USR FIRST 833kkWh,PERkWh OVER 83sk kWh, PER kWh
ECONOMIC DEVELOPMENT (EDR) - AUTOMAKER CHARGE PROVISION, PER tWl
ECONOMIC DEVELOPMENT (EDR) - INFRASTRUCTURE IMPROVEMENT PROVISION, PER kWI
TOTAL RIDERS
TOTAL PROPOSED - GS - SUBTRANSMISSION
(5)
S 1.793.280
0.43
3,20
0.00
725,951.099
2,139.952
179,696,243 546,254,856
£0.0062
£1,1270
$0.060416 $0.051400
$4,477,666
$2,411,726
$10^856,528 $28,077,300
8.00
4.31
19.39 50.14
1,212
725.951,099 725,951,099
1,821,422 11,524,430
548.628.692 561,974,545 '
725.931,099
725.951,099
725.951,099
482,670 2.011,036
270
2.139,932
725,951,099
723.951,099
725,931,099
725.951,099
2,493.756
725.951.099
3613041 S8.4 364646910.4
725.951.099
725,951,099
725.951,099
£0.000686 £0,000461
£0.004660 £0.004200 50.003640
$0,000000
£0,000096
£0,000000
$0.000000 ($5,000)
($0.005232) (£0.004468)
($0.0005)
$150,000 (£5.000)
£02640
$0,000212
$0.000000
$0,000362
$0,00315
($0,00009)
$0.001006
$0.002025 $0.001046
£0.000071
£0.000047
$0.0771
$498,002 $334,663
S8,48S $48,403
£1,997,008 £2.053.899
$0
S69.762
$0
£0 $0
(52,535) ($8,986)
(50>
$0 $0
$364,947
$153,902
SO
5262.910
$2,284,568
($215)
5730,307
$731,713 5381.457
531,489
533,826
$8,139,710
$55,998,715
0.89 0.60
0.02 0.09 3,57
0,00
0.12
OOO
0,00 0,00 (0,00) (0.02) (0.00)
0,00 0.00
1.01
0.27
0.00
0.47
4.09
(0.00)
1.30
131 0.68
0.09
0.06
U 3 4
100.00
OHIO EDISON COMPANY CASE NO. 10-XXXX-EL-SSO ESTIMATED RATE IMPACTS
ANNUALIZED RATES @ MAY 2012
BILLING UNIT DATA - 6 MONTHS ACTUAL - 6 MONTHS ESTIMATED TYPE OF FILING: ELECTRIC SECURITY PLAN (ESP)
SCHEDULE 1 PAGE 7 OF IS
RATE CODE / DESCRIPTION CUSTOMER
BILLS BILLING UNITS
MAY 2012 PROPOSED
RATES
MAY 2012 PROPOSED REVENUE
% OF TOTAL REVENUE
M. . ^ i a M. ^ JD. m (5)
GENERAL SERVICE SUBTRANSMISSION - INTERRUPTIBLE (GSU)
DISTRIBUTION CHARGES
CUSTOMER CHARGE BILLS, PER MONTH
CAPACITY CHARGE ALL kW OF BILLING DEMAND, PER kW
REACTIVE DEMAND CHARGE
ALL tfcVa, PER ikVa
TRANSFORMER CHARGE ALL kW OF BILLfflG DEMAND, PER kW
GENERATION CAPACITY CHARGES
GENERATION CAPACITY CHARGE, PER kWh
NDN-MARKET-BASBD SERVICES RIDER (NMB), PER kW
GENERATION ENERGY CHARGES
ALL SUMMER kWh, PER kWh ALL WINTER kWh, PER kWh
RIDERS
DSM / ENERGY EFFICIENCY DEMAND SIDE MANAGEMENT AND ENERGY EFFICIENCY (DSEI). PER kWh DEMAND SIDE MANAGEMENT AND ENERGY EFFICIENCY (DSE2). PER bWh
STATE kWh TAX (SKT) FIRST 2,000 kWh, PERkWh NEXT 13.000 kWh, PER kWh ABOVE 15,000 kWli, PERkWh
BUSINESS DISTRIBUTION CREDIT (BDC), PER fcWh
ADVANCED METERING INFRASTRUCTURE / MODERN GRID (AMI), PERkWh
DELTA REVENUE RECOVERY RIDER (DRR), PER kWh
ECONOMIC DEVELOPMF-NT (EDR) STANDARD CHARGE PROVISION, PERkWh INTERRUPTIBLE CREDIT PROVISION, PER KW
SCHOOL CB£DIT S.693% of GENERATION (SUMMER) SCHOOL CREDIT S.693%of GENERATION (WINTER) SCHOOL CREDIT S-693% OF CAPACITY
ECONOMIC LOAD RESPONSE (ELR) INTERRUPTIBLE PROGRAM ADMINISTRATIVE CHARGE DEMAND CURTAILABLE ENERGY CREDIT, PER KW
DELIVERY CAPITAL RECOVERY (DCR) ALL kW OF BILLING DEMAND, PER kW
NON-DISTRIBUTION LTJCOLLECTIBLE RIDER (NDU), PER bWh
DISTRIBUTION UNCOLLECTIBLE RIDER (DUN), PER kWh
DEFERRED FUEL COST (DFC), PERkWh
ALTERNATIVE ENERGY RESOURCE RIDER (AER), PER kWh
SCHOOL DISTRIBUTION CREDIT RIDER (6.693%)
GENERATION COST RECONCILIATION (GCR). PER kWh
USR FIRST S33k kWh. PER kWh OVER 833k kWh, PER kWh
ECONOMIC DEVELOPMENT (EDR) - AUTOMAKER CHARGE PROVISION, PERkWh
ECONOMIC DEVELOPMENT (EDR) - INFRASTRUCTURE IMPROVEMENT PROVISION, PER kWh
TOTAL RIDERS
TOTAL PROPOSED - CS - SUBTRANSMISSION
51.174,637 $200.00
{%)
$9,600
$166,243
$0
0.36
6.19
0.00
51,174,687
198,380
14,702,831 36,471,836
$0.0062
$1.1270
50.060416 SO 051400
5315.645
5223,574
$888,287 $1,874,652
11.76
8.33
33.09 69.83
48
48
51,174,687 51.174,687
96,000 624,000
50.454.587 31,174,687
-31.174,687
51.174,687
51.174,687 139,459
139,459
198,380
51,174,687
51.174,687
51,174,687
51,174,687
-51,174,687
25469523.75 25705163.25
51,174,687
51,174,687
51.174,687
50,000000 50.000461
50.004660 50.004200 50,003640
50.000000
$0.000096
$0.000000
$0.000000 ($5,000)
($0.005252) (50.004463)
$150000 ($5,000)
$0 2640
$0.000212
$0.000000
$0,000362
S0.(»315
($0.00009)
$0.001006
$0.002025 $0.001046
$0000071
$0.000047
$0.0525
$0 $23,592
$447 52,621
5183.655 $186,723
SO
$4,918
50
50 ($697,295)
50 $0 $0
57,200 (5697,295)
$52^72
$10,849
SO
$18,533
5161,047
SO
$51,482
$51,581 526,890
$3,630
$2,384
($793,390)
$2,684,612
aoo 0.88
0 .02
0 .10
6.84
O.DO
0 . 1 8
0 ,00
0 .00
( 2 5 9 7 )
0.00
aoo 0.00
0.27 (25,97)
195
0,40
0.00
0 6 9
6,00
0.00
1.92
1.92 1.00
0.14
0.09
(29.55)
100.00
BILLING UNIT DATA - 6 MONTHS ACTUAL - 6 MONTHS ESTIMATED TYPE OF nLING: ELECTRIC SECURITY PLAN (ESP)
OHIO EDISON COMPANY CASE NO. 10-XXXX-EL-SSO ESTIMATED RATE IMPACTS
ANNUALIZED RATES @ MAV 2012
SCHEDULE 1 PAGE 8 OF 15
RATE CODE / DESCRIPTION CUSTOMER
BILLS BILLING UNITS
MAY 2012 MAY 2012 PROPOSED PROPOSED % OF TOTAL
RATES REVENUE REVENUE
(A) (B) i£L (D) (E) JD. ($)
GENERAL SERVICE - TRANSMISSION (GT)
DISTRIBUTION CHARGES
CUSTOMER CHARGE BILLS, PER MONTH
CAPACITY CHARGE ALL kVa OF BILLING DEMAND, PER kVa
REACTIVE DEMAND CHARGE ALLrkVa.PERrkVa
TRANSFORMER CHARGE ALL kVa OF BILLING DEMAND, PER kVa
GENERATION CAPACITY CHARGES
GENERATION CAPACITY CHARGE, PER kWh
NON-MARKET BASED SERVICES RIDER (NMB), PER kW
GENERATION ENERGY CHARGES
ALL SUMMER kWh. PER kWh A LL WINTER bWh, PER kWh
DSM / ENERGY EFFICIENCY DEMAND SIDE MANAGEMENT AND ENERGY EPHQENCY (DSEI), PER kWh DEMAND SIDE MANAGEMENT AND ENERGY EFFICIENCY (DSE2), PER kWh
STATE kWh TAX (SKT) FIRST 2,000 kWh, PER kWh NEXT 13,000 kWh, PER kWh ABOVE 15.000 kWh. PER kWh
BUSINESS DISTRIBUTION CREDIT (BDC), PERkWh
ADVANCED METERING INFRASTRUCTURE / MODERN GRID (AMI), PER kWh
DELTA REVENUE RECOVERY RIDER (DRR), PER kWh
ECONOMIC DEVELOPMENT (EDR) STANDARD CREDIT PROVISION. PER kWh INTERRUPTIBLE CREDIT PROVISION. PER KW GENERAL SERVICE - TRANSMISSION PROVISION CREDIT, PER kWh GENERAL SERVICE - TRANSMISSION PROVISION CHARGE, PER kVa
ECONOMIC LOAD RESPONSE (ELR) INTERRUPTIBLE PROGRAM ADMINISTRATIVE CHARGE DEM.4ND CURTAILABLE ENERGY CREDIT, PER KW
DELIVERY CAPITAL RECOVERY (DCR) ALL kVa OF BILLING DEMAND, PER kVa
NON-DISTRIBUTION UNCOLLECTIBLE RIDER (NDU), PER kWh
DISTRIBUTION UNCOLLECTIBLE RIDER (DUN), PER kWh
DEFERRED FUEL COST (DFC), PER kWh
ALTERNATIVE ENERGY RESOURCE RIDER (AEI^, PER kWh
GENERATION COST RECONQLIATION (GCR), PER kWh
USR FIRST 833k kWh, PER kWh OVER 833k kWh, PER kWh
ECONOMIC DEVELOPMENT (EDR) - AUTOMAKER CHARGE PROVISION, PER kWh
ECONO.MIC DEVELOPMENT (EDR) - INFRASTRUCTURE IMPROVEMENT PROVISION, PER kWh
ECONOMIC DEVELOPMENT (EDR) - AUTOMAKER CREDIT PROVISION
TOTAL RIDERS
TOTAL PROPOSED - GS - TRANSMISSION
1.940 2.782,528,724
$0.00
(5)
$620,909
$3,324,980
50
SO
2,782,528,724
9,054,958
657,752,087 2,124,776,637
50.0042 $11,803,487
$0.9400 58,511,660
$0.060356 $39,699,285 $0.051349 $109,105,156
(%)
3-58
4.02
18.75 51.54
1.940
2.782,328.724 2,782,528,724
2,175,701 14.019.077
1,277,238,905 1,293,433,683
2,782,528,724
2,782,328,724
2.782,528,724
2.782,328,724 9,054,958
9,054,958
2,782,528,724
2,782,528,724
2,782,328,724
2,782,328,724
2,782,528,724
I139199763 1643328962
2,762,528,724
2,782,328,724
2.7B2,52E,724
$0.000686 $0.000460
$0.004660 $0.004200 $0.003640 __
$0.000000
50.000000
50,000000
$0.000000 ($3,000)
($0.020948)
$8,000
5150.000 (55.000)
$0000000
$0.000212
$0,000000
$0.000362
$0.00314
$0 001006
$0.002025 $0.001046
50.000014
50.0761
51,908,815 $U79,963
$10,139 $58,880
54,649,150 54;7l8:i69
$0
$0
$0
$0 so
($58,288,126) $72,439,662
$0 $0
SO
$539,896
$0
$1,007,721
58,745,488
$2,799,224
$2,307,107 $1,719,086
$0
340,279
($640,413)
$38,626,869
$211.692346
0.90 0,60
0.00 O03 2.20
0.00
0.00
0.00
0.00 0.00
(27.33) 34,22
0.00 0.00
0.00
0.28
0.00
0.48
4.13
1.32
1.09 0.81
0.00
0.02
18.25
100.00
BILLING UNIT DATA - 6 MONTHS ACTUAL - 6 MONTHS ESTIMATED TYPE OF FILING. ELECTRIC SECURITY PLAN (ESP)
OHIO EDISON COMPANY CASE NO, lO-XXXX-EL-SSO ESTIMATED RATE IMPACTS
ANNUALIZED RATES @ MAY 2012
SCHEDULE 1 PAGE 9 OF 15
LINE NO. BATE C O D E ; DESCRIPTION CUSTOMER
BILLS BILLING UNITS
WAY 2012 PROPOSED
RATES
MAV 2012 PROPOSED
, REVENUE
% O F TOTAL REVENUE
JSL (C) jm_ (E> n. (S)
GENERAL SERVICE TRANSMISSION- INTERRUPTIBLE (GT)
DISTRIBUTION CHARGES
CUSTOMER CHARGE BILLS, PER MONTH
CAPACITY CHARGE ALL kVa OF BILLING DEMAND, PER kVa
REACTIVE DEMAND CHARGE ALLikVa,PERrfcVa
TRANSFORMER CHARGE ALL kVa OF BILLING DEMAND, PER kVa
GENERATION CAPACITY CHARGES
GENERATION CAPACITY CHARGE, PER kWh
NON-MARKET-BASED SERVICES RIDER (NMB), PER kW
GENERATION ENERGY CHARGES
ALL SUMMER kWh, PER kWh ALL WINTER kWh, PER kWh
DSM / ENERGY EFFICIENCY DEMAND SIDE MANAGEMENT AND ENERGY EFTICIENCV (DSEI), PER kWh DEMAND SIDE MANAGEMENT AND ENERGY EFFICIENCY (DSE2), PER kWh
STATE kWh TAX (SKT) HRST 2,000 kWh, PER kWh NEXT 13,000 kWh, PER kWU ABOVE 15,000 kWh, PER kWh
BUSINESS DISTRIBUTION CREDIT (BDC), PER kWh
ADVANCED METERING INFRASTRUCTURE / MODERN GRID (AMI), PER kWh
DELTA REVENUE RECOVERY RIDER (DRR), PER kWh
ECONOMIC DEVELOPMENT (EDR) STANDARD CREDIT PROVISION, PER kWh INTERRUPTIBLE CREDIT PROVISION, PER kW GENERAL SERVICE - TRANSMISSION PROVISION CREDIT, PER kWh GENERAL SERVICE - TRANSMISSION PROVISION CHARGE, PER kVa
ECONOMIC LOAD RESPONSE (ELR) INTERRUPTIBLE PROGRAM ADMINISTRATIVE CHARGE DEMAND CURTAILABLE ENERGY CREDIT, PER KW
DELIVERY CAPITAL RECOVERY (DCR) ALL kVa OF BILLING DEMAND, PER kVa
NON-DISTRIBUTION UNCOLLECTIBLE RIDER (NDU), PER kWh
DISTRIBUTION UNCOLLECTIBLE RIDER (DUN). PER kWh
DEFERRED FUEL COST (DFC), PER kWh
ALTERNATIVE ENERGY RESOURCE RIDER (AER), PER fcWh
GENERATION COST RECONCILIATION (GCR). PER kWh
USR
FIRST 833k kWh, PER kWh
OVER 833k kWh. PER kWh
ECONOMIC DEVELOPMENT (EDR) - AUTOMAKER CHARGE PROVISION, PER kWh
ECONOMIC DEVELOPMENT (EDR) - INFRASTRUCTURE IMPROVEMENT PROVISION, PER kWh
ECONOMIC DEVELOPMENT (EDR) - AUTOMAKER CREDIT PROVISION
TOTAL RIDERS
TOTAL PROPOSED - GS - TRANSMISSION
204 1.276.903,808
3,494,035
1,276.903,808
3,494.035
340.679.290
936,224.318
(S)
$65,280
$1,283,010
$0.0042
$0.9400
$0.060356 $0.051349
55,416,626
53,284,393
$20,562,039 $48,074.1«
(%)
0.10
1.91
8.08
4,90
30.67 71,70
1,276,903,808 1,276,903,808
312.000 2.028,000
138,180,553 190,520,553
-1,276,903,808
1,276,903,808
1,276,903,808 2J0S,0I3
1,276.903,808 3.494,035
I
2,205,013
3.494,035
1.276.903,808
1,276.903,808
1.276,903,808
1,276,903,808
1,276,903,808
522779334,6 754124473,4
1.276,903,308
1.276,903,308
$0,000000 $0,000460
$0.004660 $0,004200 $0,003640 _
so.oooooo
$0.000000
S0.OO0O00
$0.000000 ($5000)
($0.020943) S8.000
5130.000 ($5,000)
SO.OOOOOO
$0.000212
SO.OOOOOO
50.000362
50,00314 •
50.001006
50.002025 50.001046
50.000014
50 $387,376
$1,454 $8,518
$684,977 $694,949
$0
$0
50
50 ($11,025,064) ($26,748,450) 527,952,280
$30,600 ($11,025,064)
$0
$270,704
$0
$462,443
S4 ,0U3W
$1,284,565
$1,058,733 $788,890
$0
$18,484
0,00 0,88
0.00
0.01 1.02
OOO
0.00
0.00
0.00 (1644) (39.89) 4 ) 6 9
0.05 (16,44)
0.00
0.40
0.00
0.69
5.99
1.92
1,58 118
0,00
0,03
($11,636,246) (17,33)
1.276,903,308 $67,049,294
OHIO EDISON COMPANY
CASE NO. 10-XXXX-EL-SSO
ESTIMATED RATE IMPACfS
ANNUALIZED RATES @ MAY 2012
BILLOJCT UNIT D A T A - 6 MONTHS ACTUAL - 6 MONTHS KSTIMATED
TYPE OF FILING: ELECTRIC SECURITY PLAN (ESP) SCHEDULE 1
PAGE 10 OF 13
RATE CODE / DESCRIPTION
CUSTOMER
BILLS BILLINQ UNITS
MAy20]2 MAY2012
PROPOSED PROPOSED % OF TOTAL
RATES REVENUE REVENUE
M. (D)
(%) STREET LIGHTING SERVICE (STL)
DISTRIBUTION CHARGES
5 C O M P A N Y - O W N E D , INCANDESCENT STREET L IGHTING
6 O V E R H E A D S E R V I C E . PER LAMP
7 OVERHEAD-FED W O O D SERVICE, P E R L A M P
8 O V E R H E A D FED STEEL S E R V I C E , P E R LAMP
9 U N D E R G R O U N D SERVICE, PER LAMP
10 U N D E R G R O U N D SERVICE (DUAL LAMPS) , PER LAMP
11
12 C O M P A N Y - O W N E D , FLOURESCENT STREET L IGHTING
13 O V E R H E A D - F E D STEEL SERVICE. PER LAMP
W U N D E R G R O U N D SERVICE, P E R LAMP
15 U N D E R G R O U N D SERVICE (DUAL LAMPS) , PER LAMP
16
17 C O M P A N Y - O W N E D , OVERHEAD-FED W O O D POLE U G H T I N G
18 100WATTMERCURY
19 175 W A T T M E R C U R Y
20 175 W A T T MERCURY (DUAL LAMPS)
21 250 W A T T M E R C U R Y
22 250 W A T T M E R C U R Y (DUW. LAMPS)
23 400 W A T T M E R C U R Y
14 400 W A T T M E R C U R Y (DUAL LAMPS)
25 400 W A T T M E R C U R Y (30 FT C O N C R E T E POLE)
26 400 W A T T M E R C U R Y (STEEL POLE, 2 BRACKETS)
27 700 W A T T M E R C U R Y
28 1,000 W A T T M E R C U R Y
29 70WATT HP SODIUM
30 100 W A T T HP SODIUM
31 100 W A T T H P SODIUM (DUAL LAMP)
32 100 WATT HP SODIUM (ORNAMENTAL)
n ISO WATTHP SODIUM
34 150 W A T T H P SODIUM (DUAL LAMPS)
35 200 W A T T H P SODIUM
36 21S W A T T H P SODIUM
37 250 W A T T H P SODIUM
38 250 W A T T H P SODIUM (DUAL LAMPS)
39 250 W A T T H P SODIUM (STEEL P O L E . 2 BRACKETS)
40 250 W A T T H P SODIUM ( D O W N T O W N )
41 310 W A T T HP SODIUM
42 400 W A T T HP SODIUM
43 400 W A T T HP SODIUM (DUAL LAMPS)
44 400 W A T T HP SODIUM (DUAL L A M P S , DAVIT POLE)
45 400 W A T T HP SODIUM ( D O W N T O W N )
46 1000 W A T T HP SODIUM
47
4ti C O M P A N Y - O W N E D . O V E R H E A D - F E D METAL POLE LIGHTING
43 100 W A T T MERCURY
50 175 W A T T MERCURY
51 175 W A T T M E R C U R Y (DUAL LAMPS)
52 250 W A T T M E R C U R Y
53 250 W A T T M E R C U R Y (DUAL LAMPS)
54 400 WATT MERCURY
55 400 W A T T M E R C U R Y (DUAL LAMPS)
56 400 W A T T M E R C U R Y (30 FT C O N C R E T E POLE)
57 400 W A T T M E R C U R Y (STEEL POLE. 2 BRACKETS)
; R 700 W A T T M E R C U R Y
55 1,000 W A T T M E R C U R Y
60 70 W A T T HP S O D I U M
61 100 W A T T HP SODIUM
62 100 W A T T HP SODIUM (DUAL LAMP)
63 100 W A T T HP SODIUM (ORNAMENTAL)
64 1S0WATTHPSODIUM
65 150 W A T T HP SODIUM (DUAL LAMPS)
66 200 WATT HP SODIUM
hi 215 WATT HP SODIUM
6a 250 WATT HP SODIUM
6") 250 WATT HP SODIUM (DUAL LAMPS)
70 250 W A T T HP S O D I U M (STEEL POLE, 2 BRACKETS)
71 2S0 W A T T H P S O D I U M ( D O W N T O W N )
72 310 W A T T H P S O D I U M
73 400 WATT HP SODIUM
74 «00 WATT HP SODIUM (DU«. LAMPS)
75 400 W A T T H P S O D I U M (DUAL L A M P S . DAVIT POLE)
76 400 W A T T H P SODIUM ( D O W N T O W N )
77 1000 W A T T H P S O D I U M
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.For STL (he cuitorati bills are rtonbet of lamps.
OHIO EDISON COMPANY CASE NO. 10-XXXX-tL-SSO HSTIMATED RATE IMPACTS
ANNUALIZED RATES @ MAY 2012
BILLING LTMIT DATA - 6 MONTHS ACTUAL - 6 MONTHS ESTIMATED TYPE OF FILING: ELECTRIC SECURITY PLAN (ESP)
SCHHIULEI PAGE 11 OF J5
RATE CODE / DESCRIPTION CUSTOMER
BILLS BILLING UNITS
MAY 2012 PR0P0.1ED
HATES
MAY 2012 PROPOSED REVENUE
%Ca'TOTAL REVENUE
M. (C> (Df fP>
79 C O M P A N Y - O W N E D , U N D E R G R O U N D ^ E D P O S T L IGHTING SO l O O W A T T M E R C U R Y 81 175 W A T T M E R C U R Y
82 175 W A T T M E R C U R Y (DUAL LAMPS)
S i 250 W A T T M E R C U R Y
84 250 W A T T M E R C U R Y (DUAL LAMPS)
K5 400 W A T T M E R C U R Y
86 400 W A T T MERCURY (DUAL LAMPS)
87 4 0 0 W A T T M E R C U R Y (30 FT C O N C R E T E POLE) BR 4 0 0 W A T T M E R C U R Y (STEEL POLE, 2 B R A C K E T S ) S9 700 W A T T M E R C U R Y 90 1,000 W A T T MERCURY
yi 70 WATT HP SODIUM 91 100 W A T T HP S O D I U M 93 100 W A T T HP SODIUM (DUAL LAMP)
94 100 W A T T HP S O D I U M ( O R N A M E N T A L ) 95 150 W A T T H P S O D I U M % 150 W A T T H P S O D I U M (DUAL LAMPS) 97 200 W A T T H P S O D I U M 98 215 W A T T H P S O D I U M 99 250 W A T T HP S O D I U M 100 2 5 0 W A T T H P S O D I U M (DUAL L A M P S )
101 250 W A T T H P S O D I U M (STEEL POLE, 2 B R A C K E T S ) 102 250 W A T T H P S O D I U M ( D O W N T O W N )
103 310 W A T T H P SODIUM
104 400 W A T T HP SODIUM
105 400 W A T T H P S O D I U M (DUAL LAMPS) 106 400 W A T T HP S O D I U M (DUAL L A M P S . DAVIT POLE) 107 400 W A T T H P S O D I U M ( D O W N T O W N ) IDS 1000 W A T T HP S O D I U M 109 110 C O M P A N Y - O W N E D , U N D E R G R O U N D - F E D P O L E U G H T I N G 111 l O O W A T T M E R C U R Y l U 175 W A T T M E R C U R Y 113 175 W A T T M E R C U R Y (DUAL LAMPS) 114 2 5 0 W A T T M E R C U R Y 115 250 W A T T M E R C U R Y (DUAL LAMPS) 116 400 WATT MERCURY i n 400 WATT MERCURY (DUAL LAMPS) 118 400 W A T T M E R C U R Y (30 FT C O N C R E T E POLE) 119 400 W A T T M E R C U R Y (STEEL P O L e , 2 BRACKETS)
120 700 W A T T M E R C U R Y U I 1,000 WATT MERCURY 122 70 W A T T HP SODIUM 123 100 W A T T H P S O D I U M
124 100 W A T T H P S O D I U M (DUAL LAMP)
135 100 W A T T H P S O D I U M ( O R N A M E N T A L ) 136 150 W A T T H P SODIUM
127 150 W A T T H P SODIUM (DUAL LAMPS)
i l3 200 WATT HP SODIUM 129 215 W A T T H P SODIUM
130 250 W A T T HP S O D I U M 151 250 W A T T HP SODIUM ( D U A L L A M P S )
152 250 W A T T HP S O D I U M (STEEL P O L E , 2 BRACKETS) 133 250 W A T T HP SODIUM (DOWNTOWN)
134 3 1 0 W A T T HP SODIUM
135 4 0 0 W A T T HP SODIUM
136 4 0 0 W A T T HP SODIUM ( D U A L L A M P S )
137 400 W A T T HP S O D I U M (DUAL LAMPS, DAVIT POLE) 138 400 W A T T HP S O D I U M ( D O W N T O W N ) 139 1 0 0 0 W A T T H P S O D I U M
140
141 C O M P A N Y - O W N E D , BRIDGE OR U N D E R P A S S W A L L P A C K
142 lOOWATTMERCURY H3 175 WATT MERCURY 144 175 W A T T M E R C U R Y (DUAL LAMPS) 145 250 W A T T M E R C U R Y
146 250 W A T T M E R C U R Y (DUAL LAMPS)
147 400 W A T T M E R C U R Y
148 400 W A T T M E R C U R Y (DUAL L A M P S ) 149 400 W A T T M E R C U R Y (30 FT C O N C R E T E POLE)
150 400 W A T T M E R C U R Y [STEEL POLE, 2 B R A C h l T S )
151 700 W A T T M E R C U R Y 132 I .OOOWATT M E R C U R Y 155 70 W A T T HP SODIUM 154 100 W A T T HP S O D I U M 155 100 W A T T H P S O D I U M (DUAL LAMP)
156 1 0 0 W A T T HP SODIUM (ORNAMENTAL)
157 1 5 0 W A T T H P S O D 1 U M
158 15D W A T T HP SODIUM (DUAL LAMPS)
159 200 W A T T HP S O D I U M 160 aiSWATTHPSODIUM 161 2 5 0 W A T T HP S O D I U M 162 250 W A T T HP S O D I U M [ D U A L LAMPS) 163 250 W A T T H P S O D I U M (STEEL POLE, 2 BRACKETS) 164 250 W A T T H P S O D I U M ( D O W N T O W N ) 165 310 W A T T H P SODIUM
166 400 W A T T H P S O D I U M
167 40C W A T T H P S O D I U M (DUAL LAMPS)
168 400 W A T T H P S O D I U M ( D U A L L A M P S . OAVtT POLE)
169 400 W A T T H P S O D I U M ( D O W N T O W N ) 170 1000 W A T T HP S O D I U M
USR flRST 33 3k kWh, PER kWh OVER 333k kWh, PER kWh
TOTAL RIDERS
TOTAL PROPOSED - STL - STREETLIGHl'lNG ~
25J29.948 25.329.948
7.256,309 11,688,745 6.384,894
25.329.948
25.329.948
25,329.948
25.329.948
25,329.948
25,329,948
25,329,948
23,329,948
25,329,948
25,329,948
25,329,948
S0.000686 10004452
10,004660 10.004200 10.003640
$0.000096
$0.000000
(S0.039O00)
SO.0OOO00
SO.OO0212
sooooooo
S0.000362
$0.003354
S0.001006
S0.002025 10.001046
$17,376 . $112,769
$33,814 $49,093 523,241
5106,148
$2,434
$0
($987,868)
SO
S5.370
$0
S9.173 •
$84,957
$25,482
$51,298 SO
086 556
1.67 2.42 1.15
on
0.00
(48.71
0.00
0,26
0.00
0,45
4.19
IJ6
2,53 0,00
($572,860) (28.25)
. Foi STL the cuslomer bills me runrbcr of lamps
OHIO EDISON COMPANY CASE NO. 10-XXXX-EL-SSO ESTIMATED RATE IMPACTS
ANNUALIZED RATES @ MAY 2012
BILLING UNIT DATA - 6 MONTHS ACTUAL - 5 MONTHS ESTIMATED TYPE OF FILING: ELECTRl C SECURITY PLAN (ESP)
SCHEDULE 1 PAGE 13 OF IJ
RATE C O I E / DESCRIPTION CUSTOMER
BILLS BILLING UNITS
MAY 2012 MAY 2012 PROPOSED PROPOSED % OF TOTAL
RATES REVENLE REVENUE
iiL M. (C) (D) JIL M. m (5) (%)
PWVATE OUTDOOR UGHTING SERVICE (POL)
DISTRIBUTION CHARGES
OVERHEAD-FH) WDOD POLE LIGHTING 175 WATT MERCURY 400 WATT MERCURY I.OOOWATT MERCURY HP SODIUM-I i 00 WftTTS HP SODIUM 150 WATTS HP SODIUM 150 WATTS (DOW. LAMPS) HP SODIUM 200 WATTS HP SODIUM 250 WATTS HP SODIUM 250 WATTS (DUAL LAMPS) HP SODIUM 400 WATTS HP SODIUM > 400 WATTS METAL HALIDE, ALL LAMPS
ALL OTHER INSTALLATIONS 175 WATT MERCURY 400 WATT MERCURY I.OOOWATT MERCURY HP SODIUM < 100 VJfiJJS HP SODIUM 150 WATTS HP SODIUM 150 WATTS (DUAL LAMPS) HP SODIUM 200 WATTS HP SODIUM 250 WATTS HP SODIUM 250 WATTS (DUAL LAMPS) HP SODIUM 400 WATTS HP SODIUM > 400 WATTS METAL HALIDE, ALL LAMPS
ADDITIONAL FACILITIES ALL POLES, PER POLE
GENERATION CAPACITY CHARGES
GENERATION CAPACITY CHARGE, PER kWh
NON-MARKET-BASED SERVICES RIDER (PMB), PER kWh
GENERATION ENERGY CHARGES
ALL SUMMER kWh. PER kWh ALL WINTER fcWh, PER kWh
RIDERS
DSM / ENERGY EFFICIENCY DEMAND SIDE MANAGEMENT AND ENERGY a T i a E N C Y (DSEI), PERbWh DEMAND SIDE MANAGEMENT AND ENERGY B T i a E N C Y (DSE2). PER kWh
STATE kWh TAX (SKT) FIRST 2,000 kWh, PERkWh NEXT 13,000 kWh, PER kWh ABOVE 15.000bWh. PERkWh
ADVANCED METERING INFRASTRUCTURE / MODERN GRID (AMI), PER tWh
DELTA REVENUE RECOVERY RIDER (DRR), PER kWh
134 107 120
8,218
10^76 2,493
4,969
ECX)NOMIC DEVELOPMENT (EDR) STANDARD CREDIT PROVISION, PER kWh
DELIVERY CAPITAL RECOVERY (DCR). PER kWh ALL WINTER kWh, PER fcWh
THE CLEVELAND ELECTRIC ILLUMINATING COMPANY CASE NO. 10-XXXX-EL-SSO ESTIMATED RATE IMPACTS
ANNUALIZED RATES @ MAY 2012
BILLING UNIT DATA - 6 MONTHS ACTUAL - 6 MONTHS ESTIMATED TYPE OF HLING: ELECTRIC SECURITY PLAN (ESP)
SCHEDULE 1 PAGE 3 OF 14
RATE CODE / DESCRIFnON CUSTOMER
BILLS BILLING UNITS
MAY20I2 MAY20I2 PROPOSED PROPOSED % OF TOTAL
RATES REVENUE REVENUE
M. (B) ( Q JSL J ^ iEL
GENERAL SERVICE - SECONDARY (GS)
DISTRIBUTION CHARGES
CUSTOMER CHARGE
BILLS, PER MONTH
CAPACITY CHARGE UP TO 5 kW OF BILLING DEMAND, PER MONTH
NON-BYPASSABLE GENERATION CHARGES
REACTIVE DEMAND CHARGE ALLikVa,PERrkVa
GENERATION CAPACITY CHARGES
GENERATION CAPACITY CHARGE, PER kWh
NON-MARKET-BASED SERVICES RIDER (NMB), PER kW
GENERATION ENERGY CHARGES
ALL SUMMER kWh, PER kWh ALL WINTER kWh, PER kWh
DSM / ENERGY EFFICIENCY DEMAND SIDE MANAGEMENT AND ENERGY EFHCIENCY (DSEI), PER kWh DEMAND SIDE MANAGEMENT AND ENERGY EFFICIENCY (DSE2), PER kWh
STATE kWh TAX (SKT) FIRST 2,000 kWh, PER kWh NEXT 13.000 kWh, PER kWh ABOVE 15,000 kWh, PERkWh
BUSINESS DISTRIBUTION CREDIT ( B D C ) , PER kWh
ADVANCED METERING INFRASTRUCTURE / MODERN GRID (AMI), PER kWh
DELTA REVENUE RECOVERY RIDER (DRR), PER kWh
ECONOMIC DEVELOPMENT (EDR) STANDARD CHARGE PROVISION, PERkWh SCHOOL CREDIT K.693% of GENERATION (SUMMER) SCHOOL CREDIT 8.693% of GENERATION (WINTER) SCHOOL CREDIT 8.693% OF CAPACITY
DELIVERY CAPITAL RECOVERY (DCR) UP TO 5 kW OF BILLING DEMAND, PER kW 0 V E R 3 k W , F E R k W
NON-DISTRIBUTION UNCOLLFXTIBLE RIDER (NDU), PER kWh
DISTRIBUTION UNCOLLECTIBLE RIDER (DU'N), PER kWh
DEFERRED FUEL COST (DFC), PER kWh
ALTERNATIVE ENERGY RESOURCE RIDER (AER), PER kWh
SCHOOL DISTRIBUTION CREDIT RIDER (8.693%)
GENERATION COST RECONQLIATION (GCR), PER fcWh
USR n R S T 833k kVkTi, PER kWh OVER 833k kWh, PER kWh
ECONOMIC DEVELOPME>JT (EDR) - AUTOMAKER CHARGE PROVISION, PER kWh
ECONOMIC DEVELOPMENT (EDR) - INFRASTRUCTURE IMMIOVSIENT PROVISION, PER kWh
ECONOMIC DEVELOPMENT (EDR) - AUTOMAKER CREDIT PROVISION
THE CLEVELAND H-ECTRIC ILLUMINATING COMPANY CASENO. 10-XXXX-EL-SSO ESTIMATHJ RATE IMPACTS
ANNUALIZED RATES & MAY 2012
BILLING UNIT DATA - 6 MONTHS ACTUAL - 6 MONTHS ESTIMATED
TYPE OF FILING: ELECTRIC SECURITY PLAN (ESP)
SCHH)IILE1 PAGE 4 OF 14
RATE CODE/ DESCRIPHON CUSTOMER
BILLS BILLING UNITS
MAY 2012 PROPOSED
RATES
M S Y M I 2 y . OF TOTAL
REVENUE
(A) J ^ i Q . JSL M. (F)
w <S)
GENERAL SERVICE - PRIMARY (CT)
DISTRIBUTION CHARGES
CUSTOMER CHARGE BILLS, PER MONTH
CAPACTTY CHARGE ALL kW OF BI l i lNG DEMAND, PER kW NON-BYPASSABLE GENERATION CHARGES
REACTIVE DEMAND CHARGE ALLrkVa,PERrkVa
TRANSFORMER CHARGE ALL kW OF BILLING DEMAND, PER kW
GENERATION C : A P A C I T Y CHARGES
GENHtATION CAPACITY CHARGE, PER kWh
NON MARKET-BASED SERVICES RIDER (TMB), PER kW
GENERATION ENERGY CHARGES
ALL SUMMER kWh, PER kWh ALL WINTER kWh, PER kWh
RIDERS
DSM / ENERGY EF'FICIENCY DEMAND SIDE MANAGEMENT AND ENERGY EFnCI&ICY (DSEI), PER kWh DEMAND SIDE MANAGEMENT AND ENERGY EFFICIENCY (DSE2}, PERkWh
STATE kWh TAX (SKT) FIRST 2,000 kWh, PER kWh NEXT 13,000 kWh, PER kWh ABOVE 15.000 kWh, PER kWh
BUSINESS DISTRIBUTION CREEST (BDC), PER kWh
ADVANCED METERING INFRASTRUCTURE / MODERN C31ID (AMI), PER kWh
DELTA REVENUE RECOVHIY RIDER (DRR), PER kWh
ECONOMIC DEVELOPMENT (EDR) STANDARD CHARGE PROVISION, PER kWh INTERRUPTIBLE CREDIT PROVISION, PER KW SCHOOL CREDIT 8,693% of GENERATION (SUMMER) SCHOOL CREDIT g,693% of GENERATION (WINTER) SCHOOL CREDIT 8 593% OF CAPACITY
ECONOMIC LOAD RESPONSE (ELR) INTERRUPTIBLE PROGRAM .yjMINISTRATIVE CHARGE DEMAND (XTITAILABLE ENERGY CREDIT, PER KW
DELIVERY CAPITAL RECOVERY (OCR) ALL kW OF BILLING DEMAND. PER kW
USR FIRST 833k kWh, PER kWh OVER 833k kWh, PER kWh
ECONOMIC DEVELOPMENT (EDR) - AUTOMAKER CHARGE PROVISION. PER kWh
ECONOMIC DEVELOPMENT (EDR) - INFRASTRUCTURE IMPROVEMENT PROVISION, PERkWh
TOTAL RIDERS
TOTAL PROPOSED - GS - PRIMARY
(%)
901,274
-
318,372,850
901,274
78,541,077 239,831.773
$2-4030
$0.35
$0.00
$0.0024
$0.6430
$0,062165 $0,032833
$2,167,564
SO
$0
$775,556
$579,519
$4,882,506 $12,684,223
7-88
0.00
0.00
2.82
2.11
17.75 46.12
992
318,372,850 318,372,830
1,713,687 10,824,082
384.638.685 397,198,453
42,841.959
318,372,850
318,372,830
318,372,850
722,986 2,253,500
6,776
901,274
318,372,850
318,372,850
318,372,850
318,372,850
2.976,485
318,372,850
2T7206S20.7 41166029.78
318372,850
316.372,850
318^72,850
$0.000586 $0.000677
$0,004660 50004200 50.003640
(50,005000)
50.000096
SO.OOOOOO
5 0 . 0 0 4 7 7 2
( $ 5 , 0 0 0 )
( 5 0 . 0 0 5 4 0 4 )
( 5 0 , 0 0 4 5 9 8 )
( $ 0 . 0 0 0 2 )
5 1 3 0 . 0 0 0
( $ 5 , 0 0 0 )
$ 0 . 5 2 5 0
S0,0OCM46
$ 0 . 0 0 0 0 0 0
$ 0 , 0 0 0 3 4 5
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( 5 0 , 0 0 0 7 2 )
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5000007
SOOOOII
$00864
$218,404 $215,338
57^993 $43,461
$1,400,158 $1,453,614
($214,210)
$30,395
$0
51,519,201 $0
($3,907) ($10^61)
(SI)
$0 SO
$473,169
$141,994
$0
5109,956
51,093,292
($2,153)
5279,531
$340,914 $23,382
$22,581
$34,483
56,264,995
$27,503,112
0,79 0.7S
0.03 0,17 5.09
(0.7S)
0.11
0.00
5.32 0.00 (0.01) (0.04) (0.00)
0.00 0.00
1.72
0.52
0.00
0.40
3.98
(0.01)
1.02
1.97 0.09
0.08
OL13
22.78
100.00
THE CLEVELAND ELECTRIC ILLUMINATING COMPANY CASENO. lO-XXXX-EL-SSO ESTIMATED RATE IMPACTS
ANNUALIZED RATES ® MAY 2012
B i a i N G UNTT DATA - 6 MONTHS ACTUAL - 5 MONTHS ESTIMATED TYPE OF FILING: ELECTRIC SECURITY PLAN (ESP)
SCHEDULE 1 PAGE5 OF 14
LINE NO, RATE CODE / DESCRIPTION CUSTOMER
BILLS BILLING UNFTS
" h i A Y M l i • PROPOSED
RATES
" - S i A Y 2 0 I 2 PROPOSED REVENUE
% OF TOTAL
REVENUE
J ^ iBL (Q (p) (E) JD. (5) (S)
GENERAL SERVICE PRIMARY INTERRUPTIBLE (GP)
DISTRIBUTION CHARGES
CUSTOMER CHARGE BILLS, PER MONTH
CAPACITY CHARGE ALL kW OF BILIING DEMAND, PERkW NON-BYPASSABLE GENERATION CHARGES
REACTIVE DEMAND CHARGE ALLrkVa,PERikVa
TRANSFORMER CHARGE ALL kW OF BILLING DEMAND, PER kW
GENERATION CAPACITY CHARGES
GENERATION CAPACITY CHARGE, PER tWh
NON-MARKET-BASED SERVICES RIDER (I<MB), PER kW
GENERATION ENERGY CHARGES
ALL SUMMER kWh, PER kWh ALL WINTER kWh, PER kWh
DSM / ENERGY EFFICIENCV DEMAND SIDE MANAGEMENT AND ENERGY EFFICIENCY (DSEI), PERkWh DEMAND SIDE MANAGEMENT AND ENERGY EFHCIENCY (DSE2), PER kWh
STATE kWh TAX (SKT) FIRST 2,000 kWh, PER kWh NEXT 13,000 kWh, PER kWh ABOVE 15,000 kWh, PER KWh
BUSINESS DISTRIBUTION CREDIT (BDCX PERkWh
ADVANCED MtTESING nJFRASTRUCTURE ; MODERM GRID (AMI), PER kWh
DELTA REVENUE RECOVERY RIDER (DRR). PER kWh
ECONOMIC DEVELOPMENT (EDR) STANDARD CHARGE PROVISION, PER kWh INTERRUPTIBLE CREDIT PROVISION, PER KW SCHOOL CREDIT 8,693% of GENERATION (SUMMER) SCHOOL CREDIT 8.693% of GENERATION (WINTER) SCHOOLCREDIT 8,693% OF CAPACITY
TRANSFORMER CHARGE ALL kW OF BILLING DEMAND, PER kW
GENERATIOK CAPACITV CHARGES
GENERATION CAPACTTY CHARGE, PER kWl
NON-MARKET-BASED SERVICES RIDER (NMB), PER kW
GENERATION ENERGY CHARGES
ALL SUMMER kWh. PER kWh ALL WINTER kWh, PKR kWI
RIDERS
DSM / ENERGY EFFICIENCY DEMAND SIDE MANAGEMENT AND ENERGY EFFICIENCY (DSEI), PER kWI DEMAND SIDE MANAGEMENT AND ENERGY EFFICIENCY (DSE2), PER kWl
STATE kWh TAX (SKT) FIRST 2,000 kWh. PER kWh NEXT 13,000 kWh, PER kWb ABOVE 15,000 kWh, PER kWh
BUSINESS DISTRIBUTION CREDIT (BDC). PER kWl
ADVANCED METERING INFRASTRUCTURE / MODERN GRID (AMI), PER kWl
DELTA REVENUE RECOVERY RIDER (DRR), PER kWI
ECONOMIC DEVELOPMENT (EDR) STANDARD CHARGE PROVISION. PER kWI INTERRUPTIBLE CREDIT PROVISION, PER KW SCHOOL CREDrr 8.693% Of GENERATION (SUMMER) SCHOOL CREDIT B.693% of GENERATION (WINTER) SCHOOL CREDIT 8.693% OF CAPACITY
ECONOMIC LOAD RESPONSE (ELR) INTERRUPTIBLE PROGRAM ADMINISTRATIVE CHARGt DEMAND CURTAILABLE ENERGY CREDIT, PER KW
DELIVERY CAPTTAL RECOVERY (DCR;; ALL kW OF BILLING DEMAND, PER kW
NON-DISTRIBUTION UNCOLLECTIBLE RIDER (NDU). PER kWl
DISTRIBUTION UNCOLLECTIBLE RIDER (DUN), PER kWl
DEFERRED FUEL COST (DFC), PER kWh
ALTERNATIVE ENERGY RESOURCE RIDER (AER). PER fcWl
SCHOOL DISTRIBUTION CREDIT RIDER (8.693%)
GENERATION COST RECONCILIATICW (GCR), PER kWl
USR FIRST g33k kWh. PER kWh OVER S33k kWh, PER kWh
ECONOMIC DEVELOPMENT (EDR) - AUTOMAKER CHARGE PROVISION, PER kWI
ECONOMIC DEVELOPMENT (EDR) - INFRASTRUCTURE IMPROVEMENT PROVISION, PHI kWl
ECONOMIC DEVELOPMENT (EDR) - AUTOMAKER CREDIT PROVISIO>
TOTAL RIDERS
TOTAL PROPOSED - GS - SUBTRANSMISSION
r,5S8 3,096.836,237
6.861.825
2,115,103
3.275.238
S130 00
$0.9718
$0,36
$0,54
$1,365,782
S6.568322
$751,437
$1,769,169
3,096,836,237
6,861,826
632.826,116 2,264.010,121
$0.0063
$0.9010
$0.060416 $0.051400
$19,364,317
$6,182,503
$50,316,023 $116,370,130
7,93
2.53
20.50 47.55
3,096,836,237 3.095.836,237
14.22 L128 81.138,319
2.695,952,545 2!79i;33i;992 '
3,096.836,237
3,096.836,237
3.096.836,237
5.795,084 17,342,920
50,433
6.861,826
3,096.836,237
3,096,836,237
3,096.835,237
3,096,836^37
23,138.004
3,096,836,237
2071249368 102SS86369
3,096.836,237
3.096,836.237
7.588 3.096.836.237
$0,000636 SO 000675
S0.004660 S0.004200 S0.003640
SOOOOOOO
$0 .000096
SO.OOOOOO
$0 .000000
($5 ,000)
($0 .003232)
($0 .004468)
(S0.0005)
SI 50-000
(SS.OOO)
$0 .5120
$0 ,000446
$0 .000000
50 ,000345
$0 .00334
($0 .00033 )
S0 .000878
$ 0 . 0 0 1 9 5 1
$0 0 0 0 5 6 8
SO 0 0 0 1
SO.OOQO
$0 .0789
$2 ,124 ,430
$2 ,090 ,364
$56 ,270
$340 ,865
$9 ,813 ,267
$10 ,220 ,403
$0
$297 ,598
SO
SO
SO
($30 ,436)
($77 ,492)
($27)
$0 SO
$3,513,253
$1,381,189
$0
$1,069,551
510,334,143
($6,202)
52,719.022
$4,041,529 $582,533
$219,645
$144,298
($392,793)
$41,433,714
$244,231,588
0.87 0.85
0.03 o.u 4.02
0.00
012
OOO
0.00 0,00 (0,01) (0,03) (0,00)
OOO 0,00
144
0,57
000
0.4*
4,23
(0.00)
L l l
1,65 0.24
0,09
0.06
16,96
100,00
THE CLEVELAND ELECTRIC ILLUMINATING COMPANY CASENO, 10-XXXX-EL-SSO ESTIMATED RATE IMPACTS
ANNUALIZED RATES @ MAY 1012
BB-LING UNIT DATA - 6 MONTHS ACTUAL - 6 MONTHS ESTIMATEE TYPE OF FILING: ELECTRIC SECURITY PLAN (ESF
S O S D U L E l PAGE 7 OF 14
MAV M l ! MAV !(113
RATE CODE I DESCRIPTION CUSTOMER
BILLS BILLING UNTTS %OF TOTAL
REVENUE
w isr M. GENERAL SERVICE SUBTRANSMISSION - INTERRUPTIBLE (GSO)
TRANSFORMER CHARGE ALL kW OF RILLING DEMAND. PER kW
GENERATION CAPACITY CHARGES
GENERATION CAPACFFY CHARGE, PER kWl
NON-MARKET-BASED SERVICES RIDER (NMB), PER kW
GENERATION ENERGY CHARGES
/U.L SUMMER fcWh, PER kWli ALL WINTER kWh, PER kWI
DSM / E.NEROY EFFICIENCY DEMAND SIDE MANAGEMENT AND ENERGY EFFICIENCY (DSEI), PER kWi DEMAND SKJE MANAGEMENT AND ENERGY HTICIENCY (DSE2), PHI kWl
STATE kWh TAX (SKT) FIRST 2,000 kWh, PER kWh NEXT IS.OOOkWh,PERkWh ABOVE 15.000 kWh, PER kWh
BUSINESS DISTRIBUTION CREDIT (BDC), PER kWl
ADVANCED METERING INFRASTRUCTURE / MODERN GRID (AMI). PER kWI
DELTA REVENUE RECOVERY RIMR (DRR), PER kWl
ECONOMIC DEVELOPMENT (EDR) STANDARD CHARGE PROVISION, PER kWl INTERRUPTIBLE CREDFF PROVISION, PER KW SCHOOL CREDIT 8.693% of GENERATION (SUMMER) SCHOOL CREDIT8,693% of GENERATION (WINTER) SCHOOL CRED1T8,693% OF CAPACTTY
ECONOMIC LOAD RESPONSE (ELR) INTERRUPTIBLE PROGRAM ADMINISTRATIVE CHARGE DEMAND CURTAILABLE ENERGY CREDIT, PER KW
DELIVERY CAPTTAL RECOVERY (DCR^ ALL kW OF BILLING DEMAND, PER kW
NON-DISTRIBUTION UNCOLLECTIBLE RIDER (NDU), PER kWl
DISTRIBUTION UNCOLLECTIBLE RTOER (DUN), PER kWI
DEFERRED FUEL COST (DFC), PER kWl
ALTERNATIVE ENERGY RESOURCE RIDER (AER), PER kWl
DELTA REVENUE - CEI CONTRACT
GENERATION COST RECONCILIATION (OCR), PER kWl
USR FIRST S33k kWh, PERkWh OVER S33k kWh. PER kWli
ECONOMIC DEVELOPMENT (EDR) - AUTOMAKER CHARGE PROVISION, PER kWI
ECONOMIC DEVELOPMENT (EDR) - INFRASTRUCTURE DilPROVEMENT PROVISION, PER kWI
ECONOMIC DEVELOPMENT (EDR) - AUTOMAKER CREDfl PROVISIOh
TOTAL RIDERS
TOTAL PROPOSED - GS - SUBTRANSMISSION
257,328,596
507.757
125,798
507,757
257,328,596
507.757
$130.00
50.9718
$036
10.54
$0.0063
$0.9010
S4,320
$493,438
$45387
$274,139
$1,509,076
$457,489
0.02
2.69
0.25
1.49
8.7T
2,49
74312.744 183.113,852
S0.060416
S0.DS1400
$4,483,637 $9,412,135
24.43 51.27
-
24
24
257,328,596 257,328,396
24,000 156,000
1.117,938 1,297.958 •
-237.328.596
237.328.596
257.328,596 85.884
85,884
507,737
257.326.596
257,328,596
257,328.596
257,328.596
-257.338,596
172108452.3 85220143.7
257,328.595
257,328,595
257.328,595
$0.000000 $0000675
$0.004660 $0.004200 10.003640
SO.OOOOOO
10000096
$0,000000
$0,000000 ($5,000)
($0 005253) ($0.004468)
$0,0000
$150-000 ($5,000)
$0,5120
S0.000445
50,000000
$0.000345
S0.OO334
$0.000000
S0.OOOS7S
$0,001951
$0.000566
$0.0001
$0,0000
$0.0713
SO S173.697
$112 $653
$4,069 $4,836
SO
• $24,729
50
SO ($429,422)
$0 $0 $0
S3.600 ($429,422)
$259,971
$114,769
SO
$38,873
5858,706
SO
$223,935
$335,835 $48,405
$18351
$11,990
$1,577,033
$18,356,625
0.00 095
0.00 0.00 002
0.00
0.13
0,00
0.00 (2-34) 0,00 0,00 0,00
0.02 (2.34)
1.42
0.63
0.00
0/t8
4.68
0.00
1.23
1.83 U.26
0.10
0.07
B.59
100.00
THE CLEVELAND ELECTRIC ILLUMINATING COMPANY
CASENO. 10-XXXX-EL-SSO ESTIMATED RATE IMPACTS
ANNUALIZED RATES @ MAY 2012
BILLING UNIT DATA - 6 MONTHS ACTUAL - 5 MONTHS ESTIMATED TYPE OF FILING: ELECTRIC SECURITY PLAN (ESP)
SCHEDULE 1 PAGE 3 OF 14
RATE CODE / DESCRIPTION CUSTOMER
KLLS BILLING UNITS
MAY 2012 MAY 2012 PROPOSED mOPOSED % OF TOTAL
RATES REVENUE REVENUE
i^L J ^ (C) JSL (E) (F) (S)
GENERAL SERVICE - TRANSMISSION (GT)
DISTRIBUTION CHARGES
CUSTOMER CHARGE BILLS, PER MONTH
CAPACITY CHARGE ALL fcVa OF BILLING DEMAND, PER kVa
TR.'vNSFORMER CHARGE ALL kVa OF BILLING DEMAND, PER kVa
GENERATION CAPACITY CHARGES
GENERATION CAPACITY CHARGE, PER kWh
NON-MARKET-BASED SERVICES RIDER (NMB), PER kW
GENERATION ENERGY CHARGES
ALL SUMMER kWh. PER kWh ALL WINTER kWh, PER kWh
RIDERS
DSM / ENERGY EFFI C I E N C Y DEMAND SIDE MANAGEMENT AND ENERGY E F H C I E N C Y (DSEI), PER kWh DEMAND SIDE MANAGEMENT AND ENERGY EFFICIENCY (DSE2>, PER kWh
STATE kWh TAX (SKT) FIRST 2,000 kWh, PER kWh NEXT 13,000 fcWh. PER kWh ABOVE 15,000 kWh, PER kWh
BUSINESS DISTRIBUTION CREDIT (BDC), PERkWh
ADVANCED METERING IJJFRASTRUCTUREI MODERN GRID (AMI), PER kWh
DELTA REVENUE RECOVERY RIDER (DRR). PER kWh
ECONOMIC DEVELOPMENT (EDR) STANDARD CREDTT PROVISION. PER kWh INTERRUPTIBLE CREDIT PROVISION, PER KW GENERAL SERVICE - TRANSMISSION PROVISION CREDTT. PER kWh GENERAL SERVICE - TRANSMISSION PROVISION CHARGE, PER kVa
ECONOMIC LOAD RESPONSE (ELR) INTERRUPTIBLE PROGRAM ADMINISTRATIVE CHARGE
DEMAND CURTAILABLE ENERGY CREDIT, PER KW
DELIVERY CAPITAL RECOVERY (DCR) ALL kVe OF BILLING DEMAND, PER kVa
NON-DISTRIBUTION UNCOLLECTIBLE RIDER (NDU), PER kWh
DISTRIBUTION UNCOLLECTIBLE RIDER (DUN), PER kWh
DEFERRED FUEL COST (DFC). PER kWh
ALTERNATIVE ENERGY RESOURCE RIDER (AER). PER kWh
GENERATION COST RECONCILIATION (GCR), PER kWh
USR FIRST 833kkWh, PERkWh OVER 833k kWh, PER kWh
ECONOMIC DEVELOPMENT (EDR) - AUTOMAKER CHARGE PROVISION, PER kWh
ECONOMIC DEVELOPMENT (EDR) - INFRASTRUCTURE IMPROVEMENT PROVISION, PER kWh
ECONOMIC DEVELOPMENT (EDR). AUTOMAKER CREDIT PROVISION
TOTAL RIDERS
TOTAL PROPOSED - GS - TRANSMISSION
192 1,278,689,759
2354,745
1,499350
1378,689,739
2354.745
316,245,610 952,444,149
$0.26
$0.0003
S0.7570
(5)
$61,563
52355
$0
$339,831
5333,507
$1,782,542
$0,060356 519.087320 50.051349 $49,420,345
(%)
0.51
2.35
23.15 63.15
1,278,639,739 1,278,639,759
368,115 2,392,748
493,651323 498,412,186
-
1,278,689,759
1,278,689,759
1,278,689,759
1378.689,759 2334,745
2354.745
1378.689,759
1378,689,739
1,273.689,759
1,273,689,759
1.273,689,759
907991710 370598048.6
1378,689,759
1378,689,759
192 1378.589,759
$0 000685 $0.000671
$0.004560 $0.004200 $0.003640
50.000000
SO.OOOOOO
SO.OOOOOO
SO.OOOOOO
( 5 5 . 0 0 0 )
( $ 0 . 0 2 0 9 4 8 )
5 8 - 0 0 0
$ 1 5 0 , 0 0 0
( $ 5 , 0 0 0 )
SO.OOOOOO
5 0 . 0 0 0 4 4 6
SO.OOOOOO
$ 0 . 0 0 0 3 4 5
5 0 . 0 0 3 3 3
$ 0 . 0 0 0 8 7 8
$ 0 . 0 0 1 9 5 1
$ 0 . 0 0 0 5 6 8
5 0 - 0 0 0 0 1 4
5
$ 0 . 0 5 9 3
$ 8 7 7 , 1 8 1
$ 8 3 3 , 0 0 1
$ 1 , 7 1 3
$ 1 0 , 0 5 0
$ 1 , 8 0 4 , 1 7 1
5 1 , 8 1 5 , 9 3 6
SO
$0
$0
so $0
(526,785,862) $13,837,959
SO SO
50
5570,296
$0
$441,620
$4,263,132
51,122,690
$1,771,764 5210336
$0
$18310
(600,236)
$4,723,343
"•575.831.111
1.16 1.13
D.0O 0.01 2.33
O.flO
0.00
0.00
0.00 0.00
(3531) 24.84
0.00 0,00
0.00
0.75
0.00
0,58
3.62
1,48
2,34 0,28
OOO
0,02
6,23
100.00
THE CLEVELAND ELECTRIC ILLUMINATD^G COMPANY CASENO 10-XXXX-EL-SSO ESTIMATED RATE IMPACTS
ANNUALIZED RATES @ MAY 2012
BILLING UNIT DATA - 6 MONTHS ACTUAL - 6 MONTHS ESTIMATED TYPE OF FILING: ELECTRIC SECURITY PLAN (ESP)
SCHEDULE I PAGE 9 OF 14
RATE CODE / DESCRJPTIQN CUSTOMER
BILLS BILLING UNITS
MAY 2012 MAY20I2 PROPOSED PROPOSED % OF TOTAL
RATES I^VENUE REVENUE
JAl. (B) (O (P) J2- J£L (5) (5) {%)
GENERAL SERVICE TRANSMISSION - INTERRUPTIBLE (CT)
DISTRIBUTION CHARGES
CUSTOMER CHARGE BILLS, PER MONTH
CAPACTTY CHARGE ALL kVa OF BILLiNO DEMAND, PER kVa
TRANSFORMER CHARGE ALL kVa OF BILLING DEMAND, PER kVa
GENERATION CAPACITY CHARGES
GENERATION CAPACITY CHARGE. PER fcWh
NON-MARKET-BASEP SERVICES RIDER (NMB), PER kW
GENERATION ENERGY CHARGES
ALL SUMMER kWh, PER kWh ALL WMTER kWh, PER kWTi
RIDERS
DSM/ENERGY EFFICIENCY DEMAND SIDE MANAGEMENT AND ENERGY EFRCIENCY (DSEI), PER kWh DEMAND SIDE MANAGEMENT AND ENERGY EFFICIENCY (DSE2). PER kWh
STATE kWh TAX (SKT) FIRST 2,000 kWh, PER kWh NEXT 13,000 kWh, PER kWh ABOVE 15,000 kWh. PERkWh
BUSINESS DISTRIBUTION CREDIT (BDC), PER kWi
ADVANCED .METERING INFRASTRUCTURE / MODERN GRID (AMI), PER kWh
DELTA REVENUE ReCOVERY RIDER (DRR), PER kWh
ECONOMIC DEVELOPMENT (EDR) STANDARD CREDIT PROVISION. PER kWh INTERRUPTIBLE CREDIT PROVISION. PER kW GENERAL SERVICE - TRANSMISSION PROVISION CREDIT, PER kWh GENERAL SERVICE - TRANSMISSION PROVISION CHARGE, PER kVa
ECONOMIC LOAD RESPONSE (ELR) INTERRUPTIBLE PROGRAM ADMINISTRATIVE CHARGE DEMAND CURTAILABLE ENERGY CREDIT, PER KW
DELIVERY CAPITAL RECOVERY (DCR) ALL kVa OF BILLING DEMAND, PER kVa
NON-DISTRIBUTION UNCOLLECTIBLE RIDER (NDU), PER kWh
DISTRIBUTION UNCOLLECTIBLE RIDER (DUN), PER kWh
DEFERRED FUEL COST (DFC), PER kWh
ALTERNATIVE ENES-GY RESOURCE RIDER (AER), PER kWh
GENERATION COST RECONCILIATION (GCR), PER kWh
USR FIRST S33k kWh, PER kWh OVER 833k kWh, PER kWh
ECONOMIC DEVELOPMENT (EDR) - AUTOMAKER CHARGE PROVISION, PERkWh
ECONOMIC DEVELOPMENT (EDR) - INFRASTRUCTURE IMPROVEMENT PROVISION, PER kWh
ECONOMIC DEVELOPMENT (EDR) - AUTOMAKER CREDIT PROVISION
TOTAL RIDERS
TOTAL PROPOSED - GS TRANSMISSION
1.723336
495391,139
1,723336
138395391 357,095,748
$0.0003
$0,7570
$0.060356 50,051349
511320
51,723
SO
$148,617
$1304.365
58346,957 518336,310
0.64
3.63
33,99 79,07
495391,139 495391,139
-
--
495391,139
495391,139
495391.139 1347,345
495391.139 1,723336
1347,34s
1,723336
495,391,139
495.391.139
495.391,139
495391,139
495391,139
351774966,8 143616172.2
495391,139
495391,139
50.000000 50.000671
S0.0O4660 $0.004200 $0.003640
$0.000000
$0,000000
30,000000
30.000000 ($5,000)
(50 020948) $8,000
5150.000 ($5,000)
50,000000
$0,000446
$0,000000
$0.000345
30,00333
S0.OOO878
$0.001951 $0,000368
$0.000014
$0 $332,407
$0 $0 $0
so
SO
30
SO
so ($6,236,725)
(SI03n,403) $13,786,588
55.400 ($6336,725)
SO
$220,944
SO
5171,093
51,651,634
$434,953
$686,418 $81,374
50
$7,171
0.00 1.43
0.00 0.00 0.00
QQQ
0.00
0.00
0.00 (26,89) (44,73) 39.45
0.02 (26-89)
0,00
0,95
0,00
0.74
7.12
1-88
2.96 0.35
0,00
0,03
($4,960,482) (21.39)
495391,139 $23,189.410
THE CLEVELAND ELECTRIC ILLUMINATING COMPANY
CASENO. 10-XXXX-EL-SSO
ESTIMATED RATE IMPACTS
ANNUALIZED RATES .@ MAY 2012
B\l.l.TNC, UNIT DATA - 6 MONTHS ACTUAL - 6 MONTHS EST1MATH>
TYPE OF FILING: ELECTRIC SECmUTY PLAN (ESP)
LmE NO, RATP. CODE / DESCRIPTION
(A)
CUSTOMER
BILLS BILLING UNtfS
(B) [C)
M A Y 2012
KtOPOSED
RATES
(D)
(J)
MAY 2012
PROPOSED
REVENUE
CE) CS)
W OF TOTAL
REVENUE
(F)
(%) STREET LIGHTDIG SERVICE (STL)
DISTRIBUTION CHARGES
SCHEDULEl
PAGE 10 OF 15
5 C O M P A N Y - O W N E D . INCANDESCENT STREET L IGHTING
6 O V E R H E A D SERVICE, PER LAMP
7 O V E R H E A D - F E D W O O D SERVICE. PER LAMP
8 O V E R H E A D - F E D STEEL S E R V I C E , PER LAMP
9 U N D E R G R O U N D SERVICE, PER LAMP
10 N O N - B Y P A S S A B L E GENERATION C H A R G E S
12 C O M P A N Y - O W N E D . F L O U R E S C E N T STREET L IGHTING
13 O V E R H E A D S E D STEEL S E R V I C E , P E R L A M P
14 U N D E R G R O U N D SERVICE, PER LAMP
13 U N D E R G R O U N D SERVICE (DUAL LAMPS) . PER L A M P
16
17 C O M P A N Y - O W N E D . O V E R H E A D - F E D W O O D P O L E U 0 H T 1 N 0
18 l O O W A T T M E R C U R Y
19 17S W A T T M E R C U R Y
20 176 W A T T M E R C U R Y (DUAL LAMPS)
21 250 W A T T MERCURY
22 250 W A T T M E R C U R Y (DUAL LAMPS)
23 400 W A T T MERCURY
24 400 W A T T M E R C U R Y [DUAL LAMPS)
25 400 W A T T M E R C U R Y (30 FT C O N C R E T E POLE)
26 400 W A T T M E R C U R Y (STEEL P O L E , 2 BRACKETS)
27 700 W A T T M E R C U R Y
28 1.000 W A T T M E R C U R Y
29 70 W A T T H P SODIUM
30 100 W A T T H P SODIUM
n 100 W A T T H P SODIUM (DUAL LAMP)
32 100 W A T T H P SODIUM (ORNAMENTAL)
33 150 W A T T H P SODIUM
34 150 W A T T H P SODIUM (DUAL L M f P S )
35 200 W A T T H P SODIUM
36 215 W A T T H P SODIUM
37 250 W A T T H P SODIUM
38 250 W A T T H P SODIUM (DUAL LAMPS)
35 250 W A T T H P SODIUM (STEEL POLE, 2 B R A O ^ E T S )
40 250 W A T T HP SODIUM ( D O V W T O W N )
41 310 W A T T H P SODIUM
42 400 W A T T H P S O D I U M
43 400 W A T T H P SODIUM (DUAL LAMPS)
44 400 W A T T H P SODIUM (DUAL L A M P S , DAVIT POLE)
45 400 W A T T H P S O D I U M ( D O W N T O W N )
46 1000 W A T T HP SODIUM
47
48 C O M P A N Y - O W N E D , OVERHEAD-FED METAL POLE L IGHTING
49 l O O W A T T M E R C U R Y
50 175 W A T T MERCURY
51 175 W A T T MERCURY (DUAL LAMPS)
52 250 W A T T M E R C U R Y
53 250 W A T T MERCURY (DUAL LAMPS)
54 400 W A T T MERCURY
55 400 W A T T MERCURY (DUAL LAMPS)
56 400 W A T T MERCURY (30 FT C O N C R E T E POLE)
57 400 W A T T MERCURY (STEEL POLE, 2 BRACKETS)
58 700 W A T T MERCURY
59 I . D O O W A T T M E R C U R Y
60 70 W A T T HP S O W U M
61 1 0 0 W A T T HP SODIUM
62 100 W A T T HP SODIUM (DUAL LAMP)
63 100 W A T T HP SODIUM (ORNAMENTAL)
64 150WATTHPSODIUM
65 150 W A T T HP SODIUM (DUAL LAMPS)
66 2 0 0 W A T T HP SODIUM
67 215WATTHPS001UM
68 2 S 0 W A T T HP SODIUM
69 260 W A T T HP SODIUM (DUAL LAMPS)
70 250 W A T T HP SODIUM (STEEL P O L E , 2 BRACKETS)
71 2 5 0 W A T T H P SODIUM ffPOWNTOWN)
72 310 W A T T HP SODIUM
73 4 0 0 W A T T HP SODIUM
74 400 W A T T HP SODIUM (DUAL LAMPS)
75 400 W A T T HP SODIUM (DUAL L A M P S , DAVIT POLE)
76 400 W A T T HP SODIUM ( D O W N T O W N )
17 1000 W A T T HP SODIUM
90.996
0
0
0
0
11,017
0
4,040 0
9,047
0
0
0
0
121
0
3.801
0
0
12.413
0
0
0
13,913
0
0
0
0
1,672
0
0
0
0
0
0
0
26.510.076
0
5.041,920
0
17,153,112
0
0
0
0 551,760
0
1,915,704
0
0
9,233,992
0
0
0
17,532,900
0
0
0
0
3370,432
0
0
0
0
$10.92
$0.00
io.oo £6.03
10.00
$0,00
$0,00
$0,00
$0.00
$7 39
10.00
S8.80
50.00
S ! 1.3S
SO.O0
50.00
$0.00
$0.00
S23-49
$0.00
$10,29
SO.O0
$000
$10 95
SOOO
$0,00
50.00
$13.19
SO.OO
$0.00
$0.00
$0-00
SI5.16
S0.0O
$0,00
SO.OO
SO.OO
$0.00
$0.00
SO.OO
SO.OO
SO.OO
SO.OO
$0.00
SO.OO
SO.OO
$0.00
SOOO
SO.OO
SOOO
SOOO
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$0.00
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10.00
SO.OO
SOOO
JO.OO
$0 00
JO.OO
SO.OO
SO.OO
10.00
SO.OO
SOOO
S7.33S
so $0
$4,159 $0
SO so so
so $2,339368
50
$426,624
so $1335.458
SO
$0
$0
$0
$34,107
SO $469,347
SO
so $1,631,725
$0
SO
JO 52,202.466
SO
$0
$0
$0
$304,170
JO
10
so so
so so so so so so so $0
$0
$0
10
$0
so $0
so $0
$0
so so $0
$0
$0
$0
$0
30 so 50
so so
0,04
0.00
0.00
0.02
0.00
0.00
0.00
0.00
0.00
1580
0-00
2.J7
0.00
6.87
0.00
0.00
0.00
0-00
0.19
0.00
2.61
OOO
OOO
908
0.00
0.00
0.00
12,26
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0,00
0,00
0,00
1.69
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0.00
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000
000
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0.00
0,00
. 0.00
0.00
. 0,00
0.00
0.00
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0.00
0.00
0.00
0.00
0,00
0,00
000
OOO
0.00
0.00
0.00
1, For STL Iha customer bills are mimher of lamps
THE CLEVELAND ELECTRIC ILLUMINATING COMPANY CASENO 10-XXXX-EL-SSO ESTIMATED RATE IMPACTS
ANNUALIZED RATES @ MAY 2012
BILLING UNIT DATA - 6 MONTHS ACTUAL - 6 MONTHS ESTIMATED TYPE OF FILING. ELECI'RIC SECURHY PLAN (ESP)
SCHEDULE! PAQEllCS' iS
RATR CODE / DESCRIPTION CUSTOMER
BILLS BILLING UNITS PROPOSED
RATES
MAV 2 6 1 2 — PROPOSED REVENUE
% OFTOTAL REVENUE
JA) <B_ j a . 79 C O M P A N Y - O W N E D , U N D E R G R O U N D - P E D POST LIGHTING 80 l O O W A T T M E R C U R Y 81 175 W A T T M E R C U R Y 82 175 W A T T M E R C U R Y (DUAL Lf tMPS) 83 2 5 0 W A T T M E R C U R Y 84 2 5 0 W A T T M E R C U R Y (DUAL LAMPS) 85 4 0 0 W A n MERCURY 86 4 0 0 W A T T M E R C U R Y (DUAL LAMPS) 87 400 WATT MERCURY (30 FT CONO^TE POLE) 88 4 0 0 W A T T M E R C U R Y ( S T E B . POLE , 2 BRACKETS) 89 7 0 0 W A T T M E R C U R Y 90 I .OOOWATT M E R C U R Y 91 70 W A T T H P SODIUM 92 10D W A T T HP SODIUM 93 100 W A T T HP SODIUM (DUAL LAMP) 94 10D W A T T HP SODIUM (ORNAMENTAL) 95 150 W A T T HP SODIUM 96 150 W A T T HP SODIUM (DUAL LAMPS) 97 2 0 0 W A T T HP SODIUM 98 215WATTHPSODIUM 99 2 5 0 W A T T HP SODIUM 100 2 5 0 W A T T HP SODIUM (DUAL LAMPS) 101 2 6 0 W A T T HP SODIUM (STEEL POLE. 2 BRACKETS) 102 3 5 0 W A T T HP SODIUM ( D O W N T O W N ) 103 310 W A T T HP SODIUM 104 4 0 0 W A T T HP SODIUM 105 4 0 0 W A T T HP SODIUM (DUAL LAMPS) 106 4 0 0 W A T T HP SODIUM (DUAL L A M P S , DAVIT POLE) 107 4 0 0 W A T T H P SCff l lUM (DOVWJTOWN) IDS 1000 W A T T HP SODIUM 109 110 C O M P A N Y - O W N E D . U N D E R G R O U N D - F E D POLE U G H T I N G 111 l O O W A T T M E R C U R Y 112 175 W A T T M E R C U R Y 113 175 W A T T M E R C U R Y (DUAL LAMPS) 114 250 W A T T M E R C U R Y 115 250 WATT MERCURY (DUAL LM1PS) l i s 400 WATT MERCURY 117 400 W A T T M E R C U R Y (DUAL LAMPS) 118 400 W A T T M E R C U R Y (30 FT C O N C R E T E POLE) 119 400 W A T T M E R C U R Y (STEEL POLE, 2 BRACKETS) 120 700 W A T T M E R C U R Y 121 1,000 W A T T M E R C U R Y 122 70 W A T T HP SODIUM m 100 W A T T H P S O D I U M 114 100 W A T T H P S O D I U M (DUAL LAMP) 125 100 W A T T HP S O D I U M ( O R N A M E N T A L ) 126 150 W A T T H P S O D I U M
127 150 W A T T HP S O D I U M (DUAL LAMPS) 12B 200 W A T T H P S O D I U M 129 215 W A T T H P S O D I U M 130 250 W A T T H P S O D I U M H I 250 WATT HP SODIUM (DUAL LAMPS) 132 250 W A T T H P S O D I U M (STEEL POLE, 2 BRACKETS) 133 Z50 W A T T H P S O D I U M ( D O W N T O W N ) 134 310 W A T T H P S O D I U M 135 400 W A T T H P S O D I U M
136 400 W A T T H P S O D I U M (DUAL LAMPS) 137 400 W A T T H P SODIUM (DUAL L A M P S . DAVIT POLE) 138 400 W A T T H P SODIUM ( D O W N T O W N ) 139 1000 W A T T H P S O D I U M 140 141 C O M P A N Y - O W N E D , BRIDGE O R U N D E R P A S S W A L L P A C K 142 100 W A T T M E R C U R Y 143 175 W A T T M E R C U R Y 144 175 W A T T M E R C U R Y (DUAL LAMPS) 145 250 W A T T M E R C U R Y 146 250 W A T T M E R C U R Y (DUAL LAMPS) 147 400 W A T T M E R C U R Y
US 400 W A T T M E R C U R Y (DUAL LAMPS)
149 4D0 W A T T M E R C U R Y (30 FT C O N C R E T E POLE) 150 4D0 W A T T M E R C U R Y (STEEL POLE. 2 B R A C K E T S ) 151 700 W A T T M E R C U R Y 132 I.OOOWATT M E R C U R Y 153 70 W A T T HP SODIUM 154 100 W A T T HP SODIUM 155 100 W A T T HP SODIUM (DUAL LAMP) 156 100 W A T T HP SODIUM (ORNAMENTAL) 157 150 W A T T HP SODIUM 15M 150 W A T T HP SODIUM (DUAL L A M P S ) 159 200WATTHPSGDIUM 160 215WATTHPSODIUM 161 250WATT HP SODIUM 162 2 5 0 W A T T HP SODIUM (DUAL LAMPS) 163 250 W A T T HP SODIUM (STEEL P O L E . 2 S R A C t S T S )
164 250 W A T T HP SODIUM ( D O W N T O W N ) 165 310 W A T T HP SODIUM 166 400 W A T T HP SODIUM 167 400 W A T T HP SODIUM (DUAL LAMPS) 168 400 W A T T HP SODIUM (DUAL LAMPS. D A V n POLE)
DSM / ENERGY EFnCIENCY DEMAND SIDE MANAGEMENT AND ENERGY EFFICIENCY (DSEI). PER kWl DEMAND SIDE MANAGEMENT AND ENERGY EFFICIENCY (DSE2). PER kWl
STATE kWh TAX (SKT) FIRST 2,000 kWIi. PER kWh NEXT 13,000 kWh. PER kWh ABOVE 15,000 kWh, PERkWh
ADVANCED METERING INFRASTRUCTURE / MODERN GRID (AMI), PHI tWI
DELTA REVENUE RECOVERY RIDER OJRR). PER kWI
ECONOMIC DEVELOPMENT (EDR) STANDARD CRH^FT PROVISION, PER kWl
DISTRIBUTION CUTTAL EXPENDTTURE RECOVERY (DCX ALL WPOTER kWh, PER kWl
NON-DISTRIBUTION UNCOLLECTIBLE RIDER (NDU), PER kWl
DISTRIBUTION UNCOLLECTIBLE RIDER (DUN). PER kWI
DEFERRED FUEL COST (DFC), PER kWli
ALTERNATIVE ENERGY RESOURCE RIDER (AER), PER kWl
GENERATION COST RECONCILIATION (GCR), PER kWh
USR FIRST 833k kWh, PER kWh OVER 833k kWh, PER kWh
TOTAL RIDERS
TOTAL PROPOSED - POL - PRIVATE OUTDOOR LIGHTING
62,709.024
61,709.024
15,677,256 47,031.768
S0.000027
S000017S
50.064400 $0054790
$1,693
Sn,162
$1,009,615 $2,576,871
0.02
0-10
9.45 24.11
62,709.024 62,709,024
44,861,436 12,789,696 5,057.892
62,709,024
62.709,024
62,709,024
62,709.024
62,709,024
62.709.024
62,709.024
62,709.024
62,709,024
62,709,024
62,709,024
S0.0006B6 SO.OOOOOO
S 0 . 0 0 4 6 6 0
5 0 , 0 0 * 2 0 0
5 0 , 0 0 3 6 4 0 ___
$0,0000%
50,000000
($0,022764)
$0.000000
$0,000446
SO.OOOOOO
$ 0 . 0 0 0 3 4 5
5 0 , 0 0 3 5 6
$0-000878
50 .001951
$ 0 . 0 0 0 5 6 8
$ 4 3 , 0 1 8
$0
$ 2 0 9 , 0 5 4
$53 ,717
$18 ,411
$ 2 8 1 , 1 6 2
$6 ,026
SO
($1 ,427 ,524)
SO
$ 2 7 , 9 6 8
SO
$ 2 1 , 6 5 8
$ 2 2 3 , 0 5 6
$ 5 5 , 0 5 9
$ 1 2 2 , 3 6 4
$0
($373,025)
0.40 0.00
1,96 0.50 0.17
0,06
0.00
(13,36
0,00
0.26
0.00
0.20
2.09
0-52
LIS 0.00
(5,41
1. For POL the cuslomer bills are number of lamps.
THE CLEVELAND ELECTRIC ILLUMINATING COMPANY
CASENO, 10-XXXX-EL-SSO ESTIMATED RATE IMPACTS
ANNUALIZED RATES @ MAY 2012
BILLING UNIT DATA - 6 MONTHS ACTUAL - 6 MONTHS ESTIMATED
TYPE OF FILING: ELECTRIC SECURITY PLAN (ESP) SCHEDULE 1
PAGE 14 OF 14
RATE CODE / DESCRIPTION
CUSTOMER BILLS BILLING UNITS
MAY 2012 PROPOSED
RATES
MAY 2012 PROPOSED REVENUE
%OFTOTAL REVENUE
iAi, (B) (C) (D) (E) ^ ($) (S)
TRAFFIC LIGHTING SERVICE (TRF)
DISTRIBUTION CHARGES
ALLkWh, PERkWh
GENERATION CAPACITY CHARGES
GENERATION CAPACITY CHARGE, PER kWJi
NON-MARKET-BASED SERVICES EUDER (NMB>, PER kWh
GENERATION E.NEROY CHARGES
ALL SUMMER IcWh, PER kWh ALL WINTER kWh, PER kWh
RIDERS
DSM / ENERGY EFFICIENCTY DEMAND SIDE MANAGEMENT AND ENERGY EFnOENCY p S E I ) , PER kWh DEMAND SIDE MANAGEMENT AND ENERGY EFFICIENCY p S E 2 ) , PER kWh
STATE kWh TAX (SKT) FIRST 2,000 kWh. PER kWh NEXT 13,000 kWh, PER kWh ABOVE 15.000 kWh, PER kWh
ADVANCED METERING INFRASTRUCTURE / MODERN GRID (AMI), PER kWh
DELTA REVENUE RECOVERY RIDER (DRR), PER kWh
ECONOMIC DEVELOPMENT (EDR)
STANDARD CREDIT PROVISION, PER kWh
DISTRIBUTION CAPITAL EXPENDITURE RECOVERY (DCX) ALL kWh, PER kWh
NON-DISTRIBUTION UNCOLLECTIBLE RIDER (NDU), PER kWh
DISTRIBUTION UNCOLLECTIBLE RIDER (DUN), PER kWh
DEFERRED FUEL COST (DFC), PER kWh
ALTERNATIVE ENERGY RESOURCE RIDER (AER), PER kWh
GENERATION COST RECONCILIATION (GCR), PER kWh
USR FIRST 833k kWh, PER kWh OVER S33k kWh, PER kWh
TOTAL RIDERS
TOTAL PROPOSED - TRF - TRAFFIC LIGHTING
38,711 24,237,344
24,237,344
24.237,344
6,032,282
! 8,205,062
$0.000027
$0,000178
$0,064400
$0.054790
$654
$4,314
$388,479
$997,455
($583,385)
(%)
2.38
0.08
0,52
46.96
120,58
24,237,344
24,237,344
2.144,701 7.933,569
14,159,074 24,237,344
24,237,344
24,237.344
24.237,344
24,237.344
24,237.344
24.237,344
24,237,344
24,237,344
24,237.344
24,237,344
S0.000686 S0.004509
1
ill
S0.000096
SO.OOOOOO
(S0.041555)
SO.OOOOOO
$0 .000446
SO.OOOOOO
$0 ,000345
$0 0 0 3 5 6
$0 ,000878
$0 ,001951
$0 0 0 0 5 6 8
$15 ,627
$109 ,286
$9 ,994
$33,321
$51 ,539
$94 ,854
$2 ,329
$0
($1 ,007,183)
$0
$10 ,810
SO
$8,371
$86 ,212
$21 ,280
$47 ,294
$0
2-01
13-21
1,21 4,03 6.23
0.28
0,00
(121.7
0,00
1,31
0.00
1.01
10,42
2.57
5.72 0.00
(70,52)
38,711 24,237,344 $0.0341 !K327,223 100.(»
§ 9 ^ Q LJ
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THE TOLEDO H5IS0H COMPANY CASE NO. 10-XXXX-EL-SSO ESTMATED BATE IMPACTS
ANNUALIZED RATES @ MAY 2012
BILLING UNFT DATA - 6 MONTHS ACTUAL - 6 MONTHS ESTIMATEC TYPE OF FILING. ELECTRIC SEajRITY PLAN (ESP'
SCHEDUIE 1 PAGE 3 (ff 12
LINE NO. RATE CODE / DESCRIPTION (A)
CUSTOMER BILLS
(B) BILLING UNITS
(C)
MAVaOli PROPOSH>
RATES (D)
(S)
MAV 2012 PROPOSED REVENUE
(E)
($)
%OFTOTAL REVENUE
(F)
(%) RESIDENTLU. SERVICE (RS) - TOTAL
DISTRIBUTION CHARGES
CUSTOMER CHARGE BILLS, PER MONTH
ENERGY CHARGE, PER kWh
GENERATION CAPACITY CHARGES
GENERATION CAPACITY CHAROE, PERkWl
NON-MARKET-BASED SERVICES RIDER (NMB), PER kWI
GENERATION ENERGY CHARGES
ALL SUMMER kWh. PER kWli
FIRST 500 kWh OVER 500 kWh
ALL WINTER kWh, PER fcWl
DSM / ENERGY EFFICIENCY DEMAND SIDE MANAGEMENT AND ENERGY EFFICIENCY (DSEI), PER kWI DEMAN D SIDE MANAGEMENT AND ENERGY EFFICIENCY (DSE2), PER kWl
DEMAND SIDE MANAGEMENT (DSM), PER kWl
STATE kWh TAX (SKT) FIRST 2,000 kWh, PER kWh NEXT n.OnOkWh, PERkWh ABOVE 15,000 kWh, PERkWh
RESIDENTIAL DISTRIBUTION CREDIT (RDC), PER kWl
ADVANCED METERING INFRASTRUCTURE; MODERN GRID (AMI), PER kWI
DELTA REVENUE RECOVERY RIDER (DRR), PER kWl
ECONOMIC DEVELOPMENT (EDR) WATER HEATING, PER kWh SPACE HEATING & LOAD MANAGEMENT. PER kWl
DELIVERY CAPITAL RECOVERY (DCR). PER kWI
NON-DISTRIBUTION UNCOLLECTIBLE RIDER (NDU), PER kWl
DISTRIBUTION UNCOLLECTIBLE RIDER (DUN). PER tWl
DEFERRED FUEL COST RECOVERY RlDmi (DFC). PER kWl
ALTERNATIVE ENERGY RESOURCE RIDER (AER). PER fcWl
GENESLATION COST RECONCILIATION (GCR). PER kWI
USR FIRST 855k kWh, PER kWh OVER 833k kWh, PER fcWh
RESIDENTUU. GENERATION CREDIT (RGC), PERkWl
ECONOMIC DEVELOPMENT (EDR) - AUTOMAKER CHARGE PROVISION, PER kWI
ECONOMIC DEVELOPMENT (EDR) - INFRASTRUCTURE IMPROVEMENT PROVISION. PER kWI
THE TOLEDO EDISON COMPANY CASE NO. 10-XXXX-EL-SSO ESTIMATH5 RATE IMPACTS
ANNUALIZESJ RATES @ MAY 2012
BILLING UNIT DATA - 6 MONTHS ACTUAL - 6 MONTHS ESTIMATEE TYPE OF FILING: ELECTRIC SECURTFY PLAN (ESF,
SCIM>ULE1 PAGE 3 OF 12
LINE NO, RATE CODE ; DESCRIPTION (A)
CUSTOMER BILLS
(B) BILLING UNITS
<o
MAY 2012 PROPOSED
RATES (D>
($)
MAY 2012 PROPOSED REVENUE
(E)
b)
%C«= TOTAL REVENUE
(F>
(%) GENERAL SERVICE - SECONDARY (GS)
DISTRIBUTION CHARGES
CUSTOMER CHARGE BILLS, PER MONTH
CAPACITY CHARGE UP TO 5 kW OF BILLING DEMAND, PER MONTH
NON-BYPASSABLE GENERATION CHARGES
REACTIVE DEMAND C1L\RGE ALLikVa,PERricVa
437.0
GENERATION CAPACITY CHARGES
GENERATION CAPACITY CHARGE, PERkWl
NON-MARKET-BASED SERVICES RIDER (NMB), PER kW
GENERATION ENERGY CHARGES
ALL SUMMER kWK PER kWl ALL WINTER fcWh, PER kWl
DSM/ENERGY EFFICIENCY DEMAND SIDE MANAGEMENT AND ENERGY EFFICIENCY (DSEI). PER kWI DEMAND SIDE MANAGEMENT AND ENERGY EFFICIENCY (DSE2). PE31 kWl
STATE tWh TAX (SKT) FIRST 2,000 kWh, PER kWh NEXT 13,000 kWh, PER kWh ABOVE 15,000 kWh. PER kWh
BUSINESS DISTRJBUTION CREDIT (BDC). PER kWI
ADVANCED METERING INFRASTRUCTURE / MODERN GRID (AMD, I^R kWl
DELTA REVENUE RECOVERY RIDER (DRR). PER kWl
ECONOMIC DEVELOPMENT (EDR) STANDARD CHARGE PROVISION, PER kWl SCHOOL CREDIT 8.693% of GENERATION (SUMMER) SCHOOL CREDIT 8,693%of GENERATION (WINTER) SCHOOL CREDrr 8.693% OF CAPACITY
DELIVERY CAPfTAL RECOVERY (DCR) UP TO 5 kW OF BILLING DEMAND, PER kW OVER 5 kW,PERkW
NON-DISTRIBUnON UNCOLLECTIBLE RIDER (NDU). PER kWl
DISTRIBUTION UNCOLLECTIBLE RIDER (DUN), PER kWI
DEFERRED FUEL COST (DFC), PER kWfc
ALTERNATIVE ENERGY RESOURCE RIDER (AER), PER kWI
SCHOOL DISTRIBUTION CREDrT RIDER (3,693%)
GENERATION COST RECONCILIATION (GCR), PER kWl
USR HRST 833k kWh, PER kWh OVER 833k kWh, PER kWh
ECONOMIC DEVELOPMENT (EDR) - AUTOMAKER CHARGE PROVISION, PERkWl
ECONOMIC DEVELOPMENT (EDR) - INFRASTRUCTURE IMPROVEMENT PROVISION,
THE TUXEDO HJISON COMPANY CASENO, 10-XXXX-EL-SSO ESTIMATED RATE IMPACTS
ANNUALIZED RATES @ MAY 2012
BILLING UNIT DATA - 6 MONTHS AtHUAL - 6 MONTHS ESTIMATED TYPE OF FILING ELECTRIC SECURITY PLAN (ESP)
SCH^TULBl P A < E 4 0 F I 2
LINE!*). RATE CODE / DESOUPTION (A)
CUSTOMER BILLS
(B> BILLING UNTTS
( O
MAV2DIJ PROPOSED
RATES (D)
MKYSttii PR09-OSED REVENUE
(E)
WOTTCfTAL REVENUE
(F,
GENERAL SERVICE - PRIMARY (GP)
DISTRIBUTION CHARGES
($) m
CUSTOMER CHARGE BJLLS, PER MONTH
CAPACITY CHARGE ALL kW OF BILLDJO DEMAND, PER kW NON-BYPASSABLE CffiNERATION CHARGES
BEACnVE DEMAND CHARGE ALLrkVa,PERikVa
CENKRATION CAPACITY CHARGES
GENERATION CAPACITY CHARIX, PER kWh
NON-MARKET-BASED SERVICES RIDER (NMB), PER kW
GENERATION ENERGY CHARGES
ALL SUMMER kWh, PER kWh ALL WINTER VNb, PER kWh
RIDERS
DSM / ENERGY EFFICIENCY DEMAND SIDE MANAGEMENT AND ENERGY EFFICIENCY (DSEI), PER fcWh DEMAND SIDE MANAGEMENT AND ENERGY EFFICIENCY (DSE2), PER fcWh
STATE kWh TAX (SKT) FKST 2,000kWK PERkWh NEXT 13,000 kWh, PER kWh ABOVE 15,000 kWh, PER kWh
BUSINESS DISTRIBUTION CREDIT (BDC), PERkWh
ADVANCED METERING INFRASTRUCTURE / MODERN GRID (AMI), PER kWh
DELTAREVENUERECOVERY RIDER (DRR), PERkWh
ECONOMIC DEVELOPMENT (EDRJ STANDARD CHARGE PROVISION, PERkWh INTERRUPTIBLE CREDIT PROVISION, PER KW SCHOOL CREDIT 8,693% of GENERATION (SUMMER) SCHOOL CREDIT 8,693% of GENERATION (WINTER) sa iOOL CREDIT 8,693% OF CAPACITY
ECONOMIC LOAD RESPONSE (ELR) ttJTERRUPTIBLE PROGRAM ADMINISTRATIVE CHARGE
DEMAND CURTAILABLE ENERGY CREDIT, PER KW
DELIVERY CAPITAL RECOVERY (DCR) ALL kW OF BILLING DEMAND, PER kW
NON-DISTRIBUTION U N C O L L E C T I B I X RIDER (NDU), PERkWh
DISTRIBUTION UNCOLLECTIBLE RIDER (DUN). PER kWh
DEFERRED FUEL COST (DFC), PER kWh
ALTERNATIVE ENERGY RESOLTME RIDER (AERX PER kWh
SCHOOL DISTRIBUTION CREDTT RIDER (8.693%)
GENERATION COST RECONCILIATiON (GCR). PER kWh
USR FIRST 833k kWh, PER kWh OVER 833kkWh. PERkWh
ECONOMIC DEVELOPMENT (EDR) - AUTOMAKER CHARGE PROVISION, PER kWh
ECONOMIC DEVELOPMENT (EDR) - INFRASTRUCTURE IMPROVEMENT PROVISION, PER kWh
TOTAL RIDERS
TOTAL PROPOSED - GS - PRIMARY
979,988,312
2.513.248
1.717,853
$150.00
J 1.7328
$0,36
979,988,312 979,988,312
6,668,031 43,910,798
B4S.396.252 895,975,082
21,689,577
979,988,312
979,988,112
979,988,312
8,344,315 30.359,620
10,221
2,513,248
979,98^12
979,988,312
979.988,312
979,988.313
38,903,835
979,983,312
832796650.1 147191662.2
979.988,312
979,988,312
$62^704 0.74
$4,354,956 5,16
$618,427 0.73
979,988,312
2,513,248
267.519.377 712.468.936
$0.0060
$1,1420
$0,062165 $0.052888
$5,883,830
$2,870,129
$16,630,342 $37,681,037
6,98
3,40
19,72 44.67
$0.000686 $0.000352
$0.004660 $0.00^00 $0.003640
($0.005000)
$0.000096
SO.OOOOOO
S0.004370 ($5,000)
($0.005404) ($0.00(598)
($0.0005)
$130,000 ($3,000)
$0,4850
£0,000818
$0000120
so.oofasi
$0,00353
($0,00019)
(J0.000515)
$0,002243 $0,000561
$0,00007
$0.00011
$672,272 $544,956
$31,073 $184,425
$3.077J42 $3,292,741
($108,448)
$94,174
$0
$1,218,925
$801,630
$117,399
5252,220
$3,284,921
(S7.4M)
($304,694)
0.80 0.41
0.04 0.22 3.65
(0.13)
O.U
0.00
$4,282,320 5,08 S) 0.00
($46,173) (0-05)
($139,580) (O.ITi
($3) (O-OCd
0.00 0.00
1.45
0.95
0.14
0.30
3.89
(0.01)
(0.60)
$1,867,713 2.21
582.575 0.10
$69,506 0.08
5106,148 0.13
$15,68L346 18,59
J884.346,a 100.00
THE TOLEDO EDISON CCftffANY CASE NO, 10-XXXX-EL-SSO ESTIMATED RATE IMPACTS
ANNUALIZED RATES @ MAY 3012
BILL [NG UNIT DATA - 6 MONTI IS ACTUAL - 6 MONTHS ESTIMATED TYPE OF FLING: ELECTRIC SECURITY PLAN (ESP)
SCHEDULEl PAtffi50F12
MAVWli
RATE CODE / DESCRIPTION CUST(MERBEXS BILLINO UNITS MAY 2012
TRANSFORMER CHARGE ALL kW OF BILLING DEMAND. PER fcW
GENERATION CAPACITY CHARGES
GENERATION CAPACITY CHARGE. PER kWh
NON-MARKET-BASED SERVICES RIDER (NMB), PER KW
GENERATIO> ENERGY CHARGES
ALL SUMMER tWh, PER eOJh ALL WINTER kWh, PER kWh
DSM/ENERGY EFFICIENCY DEMAND SIDE MANAGEMENT AND ENERGY EFFICIENCY (DSEI). PER kWh DEMAND SIDE MANAGEMENT AND ENERGY EFFICIENCY (DSE2), PER kWh
STATE kWh TAX (SKT) FOS.ST 1,000 kWh, PER kWh NF-XT 13.000 kWh,PFiik\Vli ABOVE 15fl00 kWh, PER kWh
BUSINESS DISTRIBUTION CREDIT (BDQ, PERkWh
ADVANCED METERING INFRASTRUCTURE/ MODERN HUD (AMI). PER kWh
DELTA REVENUE RECOVERY RIDER (DRR), PER kWh
ECONOMIC DEVE1X)PMENT (EDR) STANDARD CHARGE PROVISION, PER fcWh INTERRUPTIBLE CREDIT PROVISION, PER KW S a [OOL CREDIT 8,693% of GENERATION (SUMMER) S a [OOL CREDIT 8,693% of GENERATION (WINTER) s a !OOL CREDrr 8.693% OF CAPACnV
TRANSFORMER CHARGE ALL kVa OF BILLING DEMAND, PER kVa
GENERATION CAPACITY CHARGES
GENERATION CAPACITY OIARGE, PER kWh
NON-MARKET-BASED SERVICES RIDER (NMB), PER kW
GENERATION ENERGY CHARGES
3,673,5^,519
5,956,706
2,673,583,519
5,956,706
$320.00 $199,068 0.12
$0,1185 $705,870 0.43
50.00 SO 0.00
$0.13 $203,941 0.12
$0.0032 $8,631,122 5.33
$12300 $7,445,883 4.57
ALL SUMMER kWh, PFR kWh ALL WINTER kWh, PER kWh
DSM / ENERGY EFFICIENCY DEMAND SIDE MANAGEMENT AND ENERGY EFFICIENCV (DSEI), PER kWh DEMAND SIDE MANAGEMENT AND ENERGY EFFICIENCY (DSE2), P m i fcWh
STATE kWh TAX (SKT) FIRST 2,000 kWh, PER kWh NEXT B.OOOkWh,PERkWh ABOVE 15,000kWh, P E R k W h
BUSINESS DISTRIBUTION CREDTT (BDC). PER kWh
ADVANCED METERING INFRASTRUCTURE /MODERN GRID (AMR, P E R k W h
DELTA REVENUE RECOVERY RIDER (DRR), P H I kWh
ECONOMIC DEVELOPMENT (EDR) STANDARD CREDIT PROVISION, P E R k W h INTERRL'PTIBLE CREDTT PROVISION, PER KW GENERAL SERVICE - TRANSMISSION PROVISION a i E D I T . PER kWh GENERAL SERVICE - TRANSMISSION PROVISION CHARGE, PER kVa
ECONOMIC LOAD RESPONSE (ELR) INTERRUPTIBLE PROGRAM ADMlNISTTtATTVE CHARGE
DEMAND CURTAILABLE ENERGY CRHJTT, PFH KW
DELIVERY CAPITAL RECOVERY (DCR) ALL kVa OF BILLING DEMAND, P E R k V a
NON-DISTRIBUTION UNCOLLECTIBLE RIDER (NDU), PER kWh
DISTRIBUTION UNCOLLECTIBLE RIDER (DUN), PER kWh
DEFERRED FUEL COST (DFC), PER kWh
ALTERNATIVE ENERGY RESOURCE RIDER (AER), PER fcWh
GENERATION COST RECONOLL^TION (GCR), PER fcWb
USR FIRST 835k kWh, PER kWh OVER 833k k W ^ PER kWh
ECONOMIC DEVELOPMENT (EDR) - AUTOMAKER CHARCE HlOVISlON, PER kWh
ECONOMIC DEVELOPMENT (EDR) - INFRASTRUCTURE IMPROVEMENT PROVISION, PER kWh
ECONOMIC DEVELOPMENT (EDR) - AUTOMAKER CREDFT PROVISION
TRANSFORMER CHARGE ALL kVa OF BILLING DEMAND, PER kVa
GENERATIOK CAP.^CTTY CHARGES
(ffiNERATION CAPACITY CHARGE, PER kWh
NON-MARKET-BASED SERVICES RIDER (NMB), PER kW
GENERATION ENERGY CHARGES
ALL SUMMER kWh, PER kWh ALL WINTER kWh, PER kWh
RIDERS
DSM / ENERGY EFFICIENCY
DEMAND SIDE MANAGEMENTAND ENERGY EFFICIENCY (DSEI), PERkWh DEMAND SIDE MANAGEMENT AND ENER(3Y EFFICIENCY <DSE2), PERkWh
STATE bWh TAX (SKT) FIRST 2,000 kWh, PER kWh NEXT 13,000 kWh, PERkWh ABOVE 15,000fcWh, PERkWh
BUSINESS DISTRIBUnON CREDFT (BDC), PER kWh
ADVANCED METERING INFRASTRUCTURE / MODERN GRK) (AM), PHI kWh
DELTA REVENUE RECOVERY RIDER (DRR), PER kWh
ECONOMIC DEVELOPMENT (EDR) STANDARD CREDTT PROVISION, PER kWh INTERRUPTIBLE CREDIT PROVISION, PER kW GENERAL SERVICE - TRANSMISSION MIOVISION CREDTT. PER kWh (BNERAL SERMCE - TRANSMISSION PROVISION CHARGE. PERkVa
ECONOMIC LOAD RESPONSE (EIR) INTERRUPTIBLE PROGRAM ADMINISTRATTVE CHARGE DEMAND CURTAILABLE ENERGY CREDTT, PER KW
DELIVERY CAPITAL RE(X>VERY (DCR) ALL kVa OF BILLING DEMAND, PER kVa
NON-DISTTUBUTION UNCOLLECTIBLE RIDER (NDU), PER kWh
DISTRIBUTION UNCOLLECTIBLE RIDER (DUN), PER kWh
DEFERRED FUEL COST (DFC), PER kWh
ALTERNATIVE ENERGY RESOLTICE RIDER (AER), PER kWh
GENERATION COST RECONCILIATION (GCR), PER kWh
USR
FIRST 855k kWh. PER kWh OVER 855k kWh, PER kWh
ECONOMIC DEVELOPMENT (EDR) - AUTOMAKER CHAHCffi PROVISION, PER kWh
ECONOMIC DEVELOPMENT (EDR) - INFRASTRUCTURE IMPROVEMENT PROVISION, PER kWh
