public utilities commission of the state of … · p.o. box 800 2244 walnut grove ave. rosemead,...

P.O. Box 800 2244 Walnut Grove Ave. Rosemead, California 91770 (626) 302-3630 Fax (626) 302-4829

Akbar Jazayeri Director of Revenue and Tariffs

May 3, 2005

ADVICE 1891-E (U 338-E)

PUBLIC UTILITIES COMMISSION OF THE STATE OF CALIFORNIA ENERGY DIVISION

SUBJECT: Revisions to Clarify the Controlled Rotating Outages Provision Contained in Southern California Edison’s Tariff Schedules

Southern California Edison Company (SCE) hereby submits for filing the following changes to its tariff schedules. The revised tariff sheets are listed on Attachment A and are attached hereto.

PURPOSE

This advice filing proposes to modify a Special Condition entitled “Customers with Service Metered and Delivered at Voltage Above 50 kV (sub-transmission customers) Included in Rotating Outages” in several of SCE’s rate schedules to include clarifying language regarding when certain customers are called upon by SCE to be included in rotating outages. This filing further inserts this Special Condition, in its entirety, in other rate schedules where it should appear but it does not, and deletes it from certain other rate schedules that are applicable to a customer concurrent with a customer’s Otherwise Applicable Tariff (OAT) because it is currently included in the OAT.

BACKGROUND

On April 3, 2001, Decision (D.) 01-04-006 was issued in Phase 1 of Order Instituting Rulemaking (OIR) 00-10-002 to address the operation and approval of new and revised load curtailment, demand responsiveness, and rotating outage programs offered by Pacific Gas & Electric Company (PG&E), San Diego Gas and Electric Company (SDG&E), and SCE. The decision approved several new and revised programs and ordered the utilities to implement tariff provisions implementing these programs. One such directive of D.01-04-006 resulted in the modification of the rotating outage program so that sub-transmission customers, except those who are deemed “essential use,” Optional Binding Mandatory Curtailment program (OBMC) participants, or net suppliers

ADVICE 1891-E (U 338-E) - 2 - May 3, 2005

to the grid, must respond promptly to utility requests to drop load during rotating outages.

On March 4, 2003, SCE filed Advice 1693-E to add language to the rotating outage provision to clarify the conditions under which customers served at transmission voltage level (sub-transmission customers) are to comply with rotating outages pursuant to California Public Utilities Commission (Commission) D. 01-04-006. Consistent with D.01-04-006, the opening paragraph of the rotating outage provision was revised to provide that SCE will coordinate rotating outages for affected customers who are fossil fuel producers and pipeline operators/users to minimize disruption to public health and safety and SCE will not include a customer in a rotating outage if the customer’s inclusion would jeopardize electric system integrity.1 Another provision that was approved by the decision allowed customers an exemption from rotating outages for participating in the OBMC program, provided that SCE approves the customer’s proposed OBMC plan. Advice 1693-E became effective on May 15, 2003.

Although sub-transmission customers have not yet been requested to curtail load under the tariff provisions implemented by Advice 1693-E, the currently effective rotating outage language proposed by this Advice filing is needed because rotating outages may at times be warranted to preserve system integrity or to prevent more widespread outages. These types of infrequent outages may be deemed necessary by SCE, regardless of the conditions existing within the broader Independent System Operator (ISO)-control system. Such outages may not be the direct result of ISO requests to SCE to reduce load. Thus, SCE proposes to modify the language from the tariff provision that implies or requires ISO initiation of these types of rotating outages. TARIFF REVISIONS Clarifying text is added to Rate Schedules GS-1, TOU-GS-1, GS-2, GS2-TOU-CPP, RTP-2, RTP-2-I, TOU-GS-2, TOU-GS-2-SOP, TOU-8, TOU-8-BU, TOU-8-CPP, TOU-8-GCCD, TOU-8-SOP, PA-1, PA-2, TOU-PA, TOU-PA-CPP, TOU-PA-5, TOU-PA-7, and TOU-PA-SOP. The Special Condition entitled, Customers with Service Metered and Delivered at Voltages above 50 kV (sub-transmission customers) included in Rotating Outages provision is revised to include language in the first sentence of the first paragraph, and the first sentence of paragraph a(i) that will provide for SCE-initiated rotating outages when SCE determines such outages are warranted. This added language is needed to further clarify the conditions under which transmission level customers (sub-transmission customers) are to comply with rotating outages. SCE anticipates that SCE-initiated rotating outages may be warranted under curtain conditions in an effort to preserve system integrity or to prevent more widespread outages. The proposed tariff language would allow for both the ISO and SCE-initiated rotating outages.

For Rate Schedules TOU-GS1-CPPV-1, TOU-GS1-CPPV-2, TOU-GS1-SPP-1, TOU-GS1-SPP-2, TOU-GS2-CPPV-1, TOU-GS2-CPPV-2, TOU-GS2-SPP-1, and TOU-GS1- 1 D.01-04-006, pp. 48, 51.

ADVICE 1891-E (U 338-E) - 3 - May 3, 2005

SPP-2, the Special Condition entitled, Customers with Service Metered and Delivered at Voltages above 50 kV (sub-transmission customers) Included in Rotating Outages provision has been added. These rate schedules can be applied on stand-alone basis and should, but do not currently, contain this Special Condition.

Furthermore, for Rate Schedules GS-APS, GS-APS-E, I-6, TOU-BIP, AP-I, DBP, FC-NEM, NEM, and OBMC, the Special Condition entitled, Customers with Service Metered and Delivered at Voltages above 50 kV (sub-transmission customers) Included in Rotating Outages provision has been removed. These rate schedules are applicable concurrently with an OAT and as such, the Special Condition is not needed as it is included in the accompanying OAT.

No cost information is required for this advice filing.

EFFECTIVE DATE

It is requested that this filing become effective on the 30th calendar day after the date filed, which is June 2, 2005.

NOTICE

Anyone wishing to protest this advice filing may do so by letter via U.S. Mail, facsimile, or electronically, any of which must be received no later than 20 days after the date of this advice filing. Protests should be mailed to:

CPUC, Energy Division Attention: Tariff Unit 505 Van Ness Avenue San Francisco, California 94102 E-mail: [email protected] and [email protected]

Copies should also be mailed to the attention of the Director, Energy Division, Room 4004 (same address above).

In addition, protests and all other correspondence regarding this advice letter should also be sent by letter and transmitted via facsimile or electronically to the attention of:

Akbar Jazayeri Director of Revenue and Tariffs Southern California Edison Company 2244 Walnut Grove Avenue Rosemead, California 91770 Facsimile: (626) 302-4829 E-mail: [email protected]

ADVICE 1891-E (U 338-E) - 4 - May 3, 2005

Bruce Foster Vice President of Regulatory Operations c/o Karyn Gansecki Southern California Edison Company 601 Van Ness Avenue, Suite 2040 San Francisco, California 94102 Facsimile: (415) 673-1116 E-mail: [email protected]

There are no restrictions on who may file a protest, but the protest shall set forth specifically the grounds upon which it is based and shall be submitted expeditiously.

In accordance with Section III, Paragraph G, of General Order No. 96-A, SCE is serving copies of this advice filing to the interested parties shown on the attached GO 96-A and R.99-10-025 service list. Address change requests to the GO 96-A service list should be directed by electronic mail to [email protected] or at (626) 302-4039. For changes to all other service lists, please contact the Commission’s Process Office at (415) 703-2021 or by electronic mail at [email protected].

Further, in accordance with Public Utilities Code Section 491, notice to the public is hereby given by filing and keeping the advice filing at SCE’s corporate headquarters. To view other SCE advice letters filed with the Commission, log on to SCE’s web site at http://www.sce.com/AboutSCE/Regulatory/adviceletters.

For questions, please contact George Couts at (626) 302-6568 or by electronic mail at [email protected]

Southern California Edison Company

Akbar Jazayeri

AJ:gc:mm Enclosures

Public Utilities Commission 1891-E Attachment A

Cal. P.U.C. Sheet No. Title of Sheet

Cancelling Cal. P.U.C. Sheet No.

1

Revised 38675-E Schedule GS-1 Revised 38328-E Revised 38676-E Schedule GS-2 Revised 38339-E Revised 38677-E Schedule GS2-TOU-CPP Revised 38349-E* Original 38678-E Schedule GS2-TOU-CPP Revised 38679-E Schedule GS-APS Revised 38353-E thru

38357-E Revised 38680-E Schedule GS-APS-E Revised 38359-E thru

38363-E Revised 38681-E Schedule I-6 Revised 38373-E thru

38377-E Revised 38682-E Schedule RTP-2 Revised 38386-E Revised 38683-E Schedule RTP-2 Revised 38387-E Revised 38684-E Schedule RTP-2-I Revised 38401-E thru

Revised 38405-E Revised 38685-E Schedule TOU-BIP Revised 38409-E thru

Revised 38412-E Revised 38686-E Schedule TOU-GS-1 Revised 38422-E Revised 38687-E Schedule TOU-GS-1 Revised 38423-E Original 38688-E Schedule TOU-GS1-CPPV-1 Original 38689-E Schedule TOU-GS1-CPPV-1 Original 38690-E Schedule TOU-GS1-CPPV-1 Original 38691-E Schedule TOU-GS1-CPPV-1 Original 38692-E Schedule TOU-GS1-CPPV-2 Original 38693-E Schedule TOU-GS1-CPPV-2 Original 38694-E Schedule TOU-GS1-CPPV-2 Original 38695-E Schedule TOU-GS1-CPPV-2 Revised 38696-E Schedule TOU-GS-2 Revised 38436-E Revised 38697-E Schedule TOU-GS-2 Revised 38437-E Original 38698-E Schedule TOU-GS2-CPPV-1 Original 38699-E Schedule TOU-GS2-CPPV-1 Original 38700-E Schedule TOU-GS2-CPPV-1 Original 38701-E Schedule TOU-GS2-CPPV-1 Original 38702-E Schedule TOU-GS2-CPPV-2 Original 38703-E Schedule TOU-GS2-CPPV-2 Original 38704-E Schedule TOU-GS2-CPPV-2 Original 38705-E Schedule TOU-GS2-CPPV-2 Revised 38706-E Schedule TOU-GS-2-SOP Revised 38453-E Revised 38707-E Schedule TOU-GS-2-SOP Revised 38454-E




2

Revised 38708-E Schedule TOU-8 Revised 38470-E Revised 38709-E Schedule TOU-8-BU Revised 34934-E* Revised 38710-E Schedule TOU-8-CPP Revised 38487-E* Original 38711-E Schedule TOU-8-CPP Revised 38712-E Schedule TOU-8-CPP-GCCD Original 38500-E Revised 38713-E Schedule TOU-8-CPP-GCCD Original 38501-E Revised 38714-E Schedule TOU-8-SOP Revised 38514-E Revised 38715-E Schedule TOU-8-SOP Revised 38515-E Revised 38716-E Schedule AP - I Revised 38522-E thru

Revised 38525-E Revised 38717-E Schedule PA-1 Revised 38531-E Revised 38718-E Schedule PA-1 Revised 38532-E Revised 38719-E Schedule PA-2 Revised 38540-E Revised 38720-E Schedule PA-2 Revised 38541-E Revised 38721-E Schedule PA-RTP Revised 38550-E Revised 38722-E Schedule PA-RTP Revised 38551-E Revised 38723-E* Schedule TOU-PA Revised 38559-E* Revised 38724-E Schedule TOU-PA Revised 38560-E Revised 38725-E Schedule TOU-PA-CPP Revised 38569-E* Revised 38726-E Schedule TOU-PA-CPP Revised 38570-E* Revised 38727-E Schedule TOU-PA-5 Revised 38578-E Revised 38728-E Schedule TOU-PA-5 Revised 38579-E Revised 38729-E Schedule TOU-PA-7 Revised 38590-E Revised 38730-E Schedule TOU-PA-7 Revised 38591-E Revised 38731-E Schedule TOU-PA-SOP Revised 38601-E Revised 38732-E Schedule TOU-PA-SOP Revised 38602-E 38674-E Schedule DBP 38632-E, 37794-E*, 37795-E*,

37796-E* Revised 38733-E Schedule DBP WITHDRAW SHEET FROM

FILING Revised 33920-E* thru

33922-E* Revised 38734-E Schedule FC-NEM Original 36247-E thru

36251-E Revised 38735-E Schedule NEM Revised 35572-E,33923-E*

thru 33925-E* Revised 38736-E Schedule OBMC Revised 34393-E* 33390-E

33926-27,38636-E




3

Revised 38737-E Table of Contents Revised 38225-E Revised 38738-E Table of Contents Revised 38658-E Revised 38739-E Table of Contents Revised 38659-E Revised 38740-E Table of Contents Revised 38660-E Revised 38741-E Table of Contents Revised 38661-E

Southern California Edison Revised Cal. PUC Sheet No. 38680-E Rosemead, California Cancelling Revised Cal. PUC Sheet No. 38359-E thru 38363-E

Schedule GS-APS-E Sheet 3 GENERAL SERVICE AUTOMATIC POWERSHIFT-ENHANCED

(Continued)

(To be inserted by utility) Issued by (To be inserted by Cal. PUC) Advice 1891-E John R. Fielder Date Filed May 3, 2005 Decision 01-04-006 Senior Vice President Effective Jun 2, 2005 3H17 Resolution

SPECIAL CONDITIONS (Continued) 5. Cycling period: (Continued)

The number of cycling periods under Subsection a. and b. is unlimited during the period from the first Sunday in June to the first Sunday in October, inclusive, of each year, and a cycling period is limited to no more than 6 hours duration per day. Cycling under Subsection b. is limited to situations when SCE declares a Category One, Two, or Three Storm Alert and a condition exists that creates disruptions on SCE’s electrical distribution system which, if left unresolved, could damage the electrical system or cause a more widespread interruption in the supply of power. A Category one Storm Alert is limited to a geographical area and is considered stable; or to a widespread power outage from a transmission disturbance and the transmission and distribution systems are considered stable. A Category Two Storm Alert requires additional resources outside zone/area boundaries; or the storm is escalating and involves two or more zones/areas. A Category Three Storm Alert is a catastrophic emergency that involves multiple zones/areas, resources are fully committed, and additional assistance, such as mutual aid, are requested.

6. Air Conditioning Cycling Strategy Change: At customer's request, SCE shall change the

cycling strategy as follows:

a. Change to a lower percentage cycling strategy: The customer may change to a lower percentage cycling strategy within the first 12 months of service under this Schedule at no charge. After one change or the first 12 months, whichever is first, the customer will be charged a service fee of $30.

b. Change to a higher percentage cycling strategy: No charge to customer.

7. Direct Access (DA) and Community Choice Aggregation (CCA): A customer receiving DA or

CCA service shall notify its Energy Service Provider (ESP) or Community Choice Provider (CCP), as applicable, and Scheduling Coordinator that its air-conditioning load is subject to interruption under this Schedule.

(D)

Southern California Edison Revised Cal. PUC Sheet No. 38675-E Rosemead, California Cancelling Revised Cal. PUC Sheet No. 38328-E*

Schedule GS-1 Sheet 5 GENERAL SERVICE NON-DEMAND

(Continued)

(Continued) (To be inserted by utility) Issued by (To be inserted by Cal. PUC) Advice 1891-E John R. Fielder Date Filed May 3, 2005 Decision 01-04-006 Senior Vice President Effective Jun 2, 2005 5H19 Resolution

SPECIAL CONDITIONS (Continued) 9. Billing Calculation: (Continued

For each billing period, SCE determines the portion of total kWhs supplied by SCE’s URG and by the DWR. This determination is made by averaging the daily percentages of energy supplied to SCE’s Bundled Service Customers by SCE’s URG and by the DWR.

a. Bundled Service Customers receive Delivery Service from SCE and receive supply

(Gen) service from both SCE’s URG and the DWR. The customer’s bill is the sum of the charges for Delivery Service and Gen determined, as described in this Special Condition, and subject to applicable discounts or adjustments provided under SCE’s tariff schedules.

b. Direct Access Customers receive Delivery Service from SCE and purchase energy

from an Energy Service Provider. The customer’s bill is the sum of the charges for Delivery Service determined as described in this Special Condition except that the DWRBC rate component is subtracted from the Total Delivery Service rates before the billing determinants are multiplied by such resulting Total rates; plus the applicable charges as shown in Schedule DA and subject to applicable discounts or adjustments provided under SCE’s tariff schedules.

10. Customers with Service Metered and Delivered at Voltages above 50 kV (Sub-transmission

customers) Included in Rotating Outages. Sub-transmission customers, except for those customers exempt from rotating outages, are

to be included in controlled, rotating outages when required by the Independent System Operator (ISO) and/or SCE. To the extent feasible, SCE will coordinate rotating outages applicable to Sub-transmission customers who are fossil fuel producers and pipeline operators and users to minimize disruption to public health and safety. SCE shall not include a Sub-transmission customer in an applicable rotating outage group if the customer’s inclusion would jeopardize electric system integrity. Sub-transmission customers who are not exempt from rotating outages, and seek such exemption, may submit an Optional Binding Mandatory Curtailment (OBMC) Plan to SCE in accordance with Schedule OBMC. If SCE approves a customer’s OBMC Plan, the customer will become exempt from rotating outages and will be subject to the terms and conditions of Schedule OBMC and its associated contract.

Non-exempt Sub-transmission customers shall be required to drop their entire electrical load during applicable rotating outages by either (1) implementing the load reduction on their own initiative, in accordance with subsection a, below; or (2) having SCE implement the load reduction through remote-controlled load drop equipment (control equipment) in accordance with subsection b, below. A Sub-transmission customer shall normally be subject to the provisions of subsection a. If SCE approves a customer’s request to have SCE implement the load reduction or if the customer does not comply with prior required load reductions, as specified in subsection c, the customer will be subject to the provisions of subsection b. a. Customer-Implemented Load Reduction.

(i) Notification of Required Load Reduction. At the direction of the ISO or when SCE otherwise determines there is a need for Rotating Outage, SCE shall notify each Sub-transmission customer in an affected rotating outage group to drop its entire load. Within 30 minutes of such notification, the customer must drop its entire load. The customer shall not return the dropped load to service until 90 minutes after SCE sent the notification to the customer to drop its load, unless SCE notifies the customer that it may return its load to service prior to the expiration of the 90 minutes.

(T) (T) (T)


Schedule TOU-GS-1 Sheet 4 GENERAL SERVICE NON-DEMAND

(Continued)


SPECIAL CONDITIONS (Continued) 8. Billing Calculation: A customer’s bill is calculated according to the rates and conditions

above. Except for the Energy Charge, the charges listed in the Rates section are calculated by

multiplying the Total Delivery Service rates and the Generation rates, when applicable, by the billing determinants (e.g., per kilowatt [kW], kilowatthour [kWh], kilovar [kVa] etc.),

The Energy Charge, however, is determined by multiplying the total kWhs by the Total

Delivery Service per kWh rates to calculate the Delivery Service amount of the Charge. To calculate the Generation amount, SCE determines what portion of the total kWhs is supplied by the Utility Retained Generation (URG) and the Department of Water Resources (DWR). The kWhs supplied by the URG are multiplied by the URG per kWh rates and the kWhs supplied by the DWR are multiplied by the DWR per kWh rate and the two products are summed to arrive at the Generation amount. The Energy Charge is the sum of the Delivery Service amount and the Generation amount.

For each billing period, SCE determines the portion of total kWhs supplied by SCE’s URG

and by the DWR. This determination is made by averaging the daily percentages of energy supplied to SCE’s Bundled Service Customers by SCE’s URG and by the DWR.








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Southern California Edison Revised Cal. PUC Sheet No. 38687-E Rosemead, California (U 338-E) Cancelling Revised Cal. PUC Sheet No. 38423-E*

Schedule TOU-GS-1 Sheet 5 GENERAL SERVICE NON-DEMAND

(Continued)


SPECIAL CONDITIONS (Continued) 9. Customers with Service Metered and Delivered at Voltages above 50 kV (Sub-transmission

customers) Included in Rotating Outages. (Continued)


(i) Notification of Required Load Reduction. At the direction of the ISO or when SCE otherwise determines there is a need for Rotating Outage, SCE shall notify each Sub-transmission customers in an affected rotating outage group to drop itstheir entire load. Within 30 minutes of such notification, the customer must drop its entire load. The customer shall not return the dropped load to service until 90 minutes after SCE sent the notification to the customer to drop its load, unless SCE notifies the customer that it may return its load to service prior to the expiration of the 90 minutes.

(ii) Method of Notification. SCE will notify Sub-transmission customers who are

required to implement their own load reduction via telephone, by either an automated calling system or a manual call to a business telephone number or cellular phone number designated by the customer. The designated telephone number will be used for the sole purpose of receiving SCE’s rotating outage notification and must be available to receive the notification at all times. When SCE sends the notification to the designated telephone number the customer is responsible for dropping its entire load in accordance with subsection a. (i)., above. The customer is responsible for informing SCE, in writing, of the telephone number and contact name for purposes of receiving the notification of a rotating outage.

(iii) Excess Energy Charges. If a Sub-transmission customer fails to drop its

entire load within 30 minutes of notification by SCE, and/or fails to maintain the entire load drop until 90 minutes after the time notification was sent to the customer, unless SCE otherwise notified the customer that it may return its load to service earlier in accordance with subsection a. (i) above, SCE shall assess Excess Energy Charges of $6 per kWh for all kWh usage in excess of the Authorized Residual Ancillary Load. Such charges will be based on the total kWh usage during the applicable rotating outage penalty period, less the product of Authorized Residual Ancillary Load in kW and the applicable rotating outage penalty period in hours. Excess Energy Charges will be determined and applied by SCE subsequent to the Sub-transmission customer’s regularly scheduled meter read date following the applicable rotating outage.

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Schedule GS-2 Sheet 8 GENERAL SERVICE - DEMAND

(Continued)







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Schedule TOU-BIP Sheet 4 TIME-OF-USE-GENERAL SERVICE BASE INTERRUPTIBLE PROGRAM

(Continued)


SPECIAL CONDITIONS (Continued) 13. Insurance. Insurance may not be used to pay non-compliance penalties for willful failure to

comply with a Notice of Interruption. Existing and new customers will not be eligible for continued service or new service under this Schedule unless a declaration is signed under penalty or perjury which states that the customer does not have, and will not obtain, any insurance for the purpose of the insurance paying non-compliance penalties for willful failure to comply with Notices of Interruptions. Continued eligibility and new eligibility under this Schedule will require that each customer execute a declaration stating that it does not have, and will not obtain, such insurance. For any customer with such insurance after the effective date of this Special Condition, service under this Schedule will be terminated and such customer will be required to pay back the interruptible rate discounts for the period covered by the insurance. If the period cannot be determined, the recovery shall be for the entire period the customer was on this Schedule.

14. Essential Use Customers. Customers electing to receive service under this Schedule and

who are classified as Essential Use in accordance with Commission Decision No. 91548 must provide proof of back-up generation or other means to supply energy for interruptible load. A declaration must be signed under penalty of perjury and must state that the customer is, to the best of that customer’s understanding, an Essential Use customer under Commission rules. It must also state that the customer voluntarily elects to participate in an interruptible program for part of or all of its load upon request by SCE, while continuing to meet its essential needs based on adequate back-up generation or other means. Furthermore, such customer must set its Firm Service Level at no less than 50 percent of its load. Absent such declaration, SCE may find the customer ineligible to receive service under this Schedule.

(D)


Schedule TOU-8 Sheet 13 TIME-OF-USE - GENERAL SERVICE - LARGE

(Continued)


SPECIAL CONDITIONS (Continued) 17. Billing Calculation: (Continued) For each billing period, SCE determines the portion of total kWhs supplied by SCE’s URG











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Schedule TOU-8-BU Sheet 7 TIME-OF-USE - GENERAL SERVICE - LARGE BACK-UP SERVICE

(Continued)


SPECIAL CONDITIONS (Continued) 13. Back-Up Service Not A Guarantee Of Uninterrupted Electric Service. Back-up service under

this Schedule does not prevent a customer from being subject to rotating outages. In the event the customer is designated by the California Public Utilities Commission’s decisions or staff as exempted essential use, the back-up service shall not be deemed as essential nor exempt from rotating outages.


customers) Included in Rotating Outages.

Sub-transmission customers, except for those customers exempt from rotating outages, are to be included in controlled, rotating outages when required by the Independent System Operator (ISO) and/or SCE. To the extent feasible, SCE will coordinate rotating outages applicable to Sub-transmission customers who are fossil fuel producers and pipeline operators and users to minimize disruption to public health and safety. SCE shall not include a Sub-transmission customer in an applicable rotating outage group if the customer’s inclusion would jeopardize electric system integrity. Sub-transmission customers who are not exempt from rotating outages, and seek such exemption, may submit an Optional Binding Mandatory Curtailment (OBMC) Plan to SCE in accordance with Schedule OBMC. If SCE approves a customer’s OBMC Plan, the customer will become exempt from rotating outages and will be subject to the terms and conditions of Schedule OBMC and its associated contract.



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Schedule RTP-2 Sheet 9 GENERAL SERVICE - LARGE REAL TIME PRICING

(Continued)





The Energy Charge, however, is determined by multiplying the total hourly kWhs by the Total

Delivery Service per kWh rates in each hour and the products are summed to calculate the Delivery Service amount of the Charge. To calculate the Generation amount, SCE determines what portion of the total kWhs is supplied by the Utility Retained Generation (URG) and the Department of Water Resources (DWR). The hourly kWhs supplied by the URG are multiplied by the URG per kWh rates in each hour and the hourly kWhs supplied by the DWR are multiplied by the DWR per kWh rate and the hourly products are summed to arrive at the Generation amount. The Energy Charge is the sum of the Delivery Service amount and the Generation amount.







13 Customers with Service Metered and Delivered at Voltages above 50 kV (Sub-transmission



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Schedule RTP-2 Sheet 10 GENERAL SERVICE - LARGE REAL TIME PRICING

(Continued)



customers) Included in Rotating Outages. (Continued) Non-exempt Sub-transmission customers shall be required to drop their entire electrical load during applicable rotating outages by either (1) implementing the load reduction on their own initiative, in accordance with subsection a, below; or (2) having SCE implement the load reduction through remote-controlled load drop equipment (control equipment) in accordance with subsection b, below. A Sub-transmission customer shall normally be subject to the provisions of subsection a. If SCE approves a customer’s request to have SCE implement the load reduction or if the customer does not comply with prior required load reductions, as specified in subsection c, the customer will be subject to the provisions of subsection b. a. Customer-Implemented Load Reduction.



required to implement their own load reduction via telephone, by either an automated calling system or a manual call to a business telephone number or cellular phone number designated by the customer. The designated telephone number will be used for the sole purpose of receiving SCE’s rotating outage notification and must be available to receive the notification at all times. When SCE sends the notification to the designated telephone number the customer is responsible for dropping its entire load in accordance with subsection a. (i), above. The customer is responsible for informing SCE, in writing, of the telephone number and contact name for purposes of receiving the notification of a rotating outage.



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Schedule GS-APS Sheet 3 GENERAL SERVICE AUTOMATIC POWERSHIFT

(Continued)


SPECIAL CONDITIONS (Continued) 5. Cycling period: (Continued)

The number of cycling periods under Subsection a. and b. is limited to 15 occurrences per year during the period from the first Sunday in June to the first Sunday in October, inclusive, of each year, and a cycling period is limited to no more than 6 hours duration per day. Cycling under Subsection b. is limited to situations when SCE declares a Category One, Two, or Three Storm Alert and a condition exists that creates disruptions on SCE’s electrical distribution system which, if left unresolved, could damage the electrical system or cause a more widespread interruption in the supply of power. A Category one Storm Alert is limited to a geographical area and is considered stable; or to a widespread power outage from a transmission disturbance and the transmission and distribution systems are considered stable. A Category Two Storm Alert requires additional resources outside zone/area boundaries; or the storm is escalating and involves two or more zones/areas. A Category Three Storm Alert is a catastrophic emergency that involves multiple zones/areas, resources are fully committed, and additional assistance, such as mutual aid, are requested.

6. Air Conditioning Cycling Strategy Change: At customer's request, SCE shall change the

cycling strategy as follows:

a. Change to a lower percentage cycling strategy: The customer may change to a lower percentage cycling strategy within the first 12 months of service under this Schedule at no charge. After one change or the first 12 months, whichever is first, the customer will be charged a service fee of $30.

b. Change to a higher percentage cycling strategy: No charge to customer.

7. Direct Access (DA) and Community Choice Aggregation (CCA): A customer receiving DA or

CCA service shall notify its Energy Service Provider (ESP) or Community Choice Provider (CCP), as applicable, and Scheduling Coordinator that its air-conditioning load is subject to interruption under this Schedule.

(D)


Schedule GS2-TOU-CPP Sheet 9 GENERAL SERVICE-TIME-OF-USE-DEMAND METERED CRITICAL PEAK PRICING-VOLUMETRIC CHARGE DISCOUNT-VCD

(Continued)





Non-exempt Sub-transmission customers shall be required to drop their entire electrical load during applicable rotating outages by either (1) implementing the load reduction on their own initiative, in accordance with subsection a, below; or (2) having SCE implement the load reduction through remote-controlled load drop equipment (control equipment) in accordance with subsection b, below. A Sub-transmission customer shall normally be subject to the provisions of subsection a. If SCE approves a customer’s request to have SCE implement the load reduction or if the customer does not did not comply with prior required load reductions, as specified in subsection c, the customer will be subject to the provisions of subsection b.

a. Customer-Implemented Load Reduction.

(i) Notification of Required Load Reduction. At the direction of the ISO or when SCE otherwise determines there is a need for Rotating Outage, SCE shall notify each Sub-transmission customers in an affected rotating outage group to drop its entire load. Within 30 minutes of such notification, the customer must drop its entire load. The customer shall not return the dropped load to service until 90 minutes after SCE sent the notification to the customer to drop its load, unless SCE notifies the customer that it may return its load to service prior to the expiration of the 90 minutes.



(T) (T) (T)

Southern California Edison Original Cal. PUC Sheet No. 38678-E Rosemead, California Cancelling Cal. PUC Sheet No.

Schedule GS2-TOU-CPP Sheet 12 GENERAL SERVICE-TIME-OF-USE-DEMAND METERED CRITICAL PEAK PRICING-VOLUMETRIC CHARGE DISCOUNT-VCD

(Continued)



customers) Included in Rotating Outages. (Continued) d. Net-Generators

Sub-transmission customers who are also net-generators are normally exempt from rotating outages, but they must be net suppliers of power to the grid during all rotating outages. For the purpose of this Special Condition, a net-generator is an SCE customer who operates an electric generating facility as part of its industrial or commercial process, and the generating facility normally produces more electrical power than is consumed in the industrial or commercial process, with the excess power supplied to the grid. Sub-transmission customers whose primary business purpose is to generate power are not included in this Special Condition. (i) Notification of Rotating Outages. SCE will notify sub-transmission customers

who are net-generators of all rotating outages applicable to customers within SCE’s service territory. Within 30 minutes of notification, the customer must ensure it is a net supplier of power to the grid throughout the entire rotating outage period. Failure to do so will result in the customer losing its exemption from rotating outages, and the customer will be subject to Excess Energy Charges, as provided below.

(ii) Excess Energy Charges. Net generators who are not net suppliers to the grid

during each rotating outage period will be subject to Excess Energy Charges of $6 per kWh for all kWh usage in excess of the Authorized Residual Ancillary Load. Such charges will be based on the total kWh usage during a rotating outage penalty period, less the product of Authorized Residual Ancillary Load in kW and the applicable rotating outage period hours. Excess Energy Charges will be determined and applied by SCE subsequent to the customer’s regularly scheduled meter read date following the applicable rotating outage. Excess Energy Charges shall not apply during periods of verifiable scheduled generator maintenance or if the customer’s generator suffers a verifiable forced outage. The scheduled maintenance must be approved in advance by either the ISO or SCE, but approval may not be unreasonably withheld.


Schedule I-6 Sheet 11 TIME-OF-USE GENERAL SERVICE - LARGE - INTERRUPTIBLE

(Continued)



comply with a Notice of Interruption. Existing and new customers will not be eligible for continued service or new service under this Schedule unless a declaration is signed under penalty of perjury which states that the customer does not have, and will not obtain, any insurance for the purpose of the insurance paying non-compliance penalties for willful failure to comply with Notices of Interruptions. Continuing eligibility and new eligibility under this Schedule will require that each customer execute a declaration stating that it does not have, and will not obtain, such insurance. For any customer with such insurance after the effective date of this Special Condition, service under this Schedule will be terminated and such customer will be required to pay back the interruptible rate discounts for the period covered by the insurance. If the period cannot be determined, the recovery shall be for the entire period the customer was on this Schedule.

19. Essential Use Customers. Customers receiving service under this Schedule and who are

classified as Essential Use in accordance with Commission Decision No. 91548 must provide proof of adequate back-up generation or other means to supply energy for interruptible load. A declaration must be signed under penalty of perjury and must state that the customer is, to the best of that customer’s understanding, an Essential Use customer under Commission rules. It must also state that the customer voluntarily elects to participate in an interruptible program for part of or all of its load upon request by SCE, while continuing to meet its essential needs based on adequate backup generation or other means. Furthermore, such customer must adjust its Firm Service Level to equal no less than 50 percent its load. Customer must sign an Amendment to Contract for Interruptible Service (Form 14-332). Absent such declaration and absent an execution of Form 14-332, if applicable, SCE may find the customer ineligible to receive service under this Schedule.

(T) (T) (D)


Schedule RTP-2-I Sheet 12 GENERAL SERVICE - LARGE REAL TIME PRICING - INTERRUPTIBLE

(Continued)



comply with a Notice of Interruption. Existing and new customers will not be eligible for continued service or new service under this Schedule unless a declaration is signed under penalty of perjury which states that the customer does not have, and will not obtain, any insurance for the purpose of the insurance paying non-compliance penalties for willful failure to comply with Notices of Interruptions. Continuing eligibility and new eligibility under this Schedule will require that each customer execute a declaration stating that it does not have, and will not obtain, such insurance. For any customer with such insurance after the effective date of this Special Condition, service under this Schedule will be terminated and such customer will be required to pay back the interruptible rate discounts for the period covered by the insurance. If the period cannot be determined, the recovery shall be for the entire period the customer was on this Schedule.

19. Essential Use Customers. Customers receiving service under this Schedule and who are

classified as Essential Use in accordance with Commission Decision No. 91548 must provide proof of adequate back-up generation or other means to supply energy for interruptible load. A declaration must be signed under penalty of perjury and must state that the customer is, to the best of that customer’s understanding, an Essential Use customer under Commission rules. It must also state that the customer voluntarily elects to participate in an interruptible program for part of or all of its load upon request by SCE, while continuing to meet its essential needs based on adequate backup generation or other means. Furthermore, such customer must adjust its Firm Service Level to equal no less than 50 percent its load. Customer must sign an Amendment to Contract for Interruptible Service (Form 14-332). Absent such declaration and absent an execution of Form 14-332, if applicable, SCE may find the customer ineligible to receive service under this Schedule.

(D)

Southern California Edison Original Cal. PUC Sheet No. 38688-E Rosemead, California (U 338-E) Cancelling Cal. PUC Sheet No.

Schedule TOU-GS1-CPPV-1 Sheet 5 TIME-OF-USE GENERAL SERVICE - STATEWIDE PRICING PILOT CRITICAL PEAK PRICING- VARIABLE PERIOD

(Continued)











(Continued)




a. Customer-Implemented Load Reduction. (Continued)

(iii) Excess Energy Charges. If a Sub-transmission customer fails to drop its entire load within 30 minutes of notification by SCE, and/or fails to maintain the entire load drop until 90 minutes after the time notification was sent to the customer, unless SCE otherwise notified the customer that it may return its load to service earlier in accordance with subsection a. (i) above, SCE shall assess Excess Energy Charges of $6 per kWh for all kWh usage in excess of the Authorized Residual Ancillary Load. Such charges will be based on the total kWh usage during the applicable rotating outage penalty period, less the product of Authorized Residual Ancillary Load in kW and the applicable rotating outage penalty period in hours. Excess Energy Charges will be determined and applied by SCE subsequent to the Sub-transmission customer’s regularly scheduled meter read date following the applicable rotating outage.

(iv) Authorized Residual Ancillary Load. Authorized Residual Ancillary Load is

load that is deemed to be equivalent to five percent of the Sub-transmission customer’s prior billing month’s recorded Maximum Demand. This minimum load level is used as a proxy to allow for no-load transformer losses and load attributed to minimum grid parallel operation for generators connected under Rule 21.



(Continued)




b. SCE-Implemented Load Reduction.

Non-exempt Sub-transmission customers may request, in writing, to have SCE drop the customer’s entire load during all applicable rotating outages using SCE’s remote-controlled load drop equipment (control equipment). If SCE agrees to such arrangement, SCE will implement the load drop by using one of the following methods:

(i) Control Equipment Installed. For a Sub-transmission customer whose load can

be dropped by SCE’s existing control equipment, SCE will implement the load drop during a rotating outage applicable to the customer. The customer will not be subject to the Notification and Excess Energy Charge provisions set forth in subsection a, above.

(ii) Control Equipment Pending Installation. For a Sub-transmission customer

whose load can not be dropped by SCE’s existing control equipment, the customer must request the installation of such equipment at the customer’s expense in accordance with SCE’s Rule 2, Section H, Added Facilities. Pending the installation of the control equipment, the customer will be responsible for dropping load in accordance with the provisions of subsection a, above, including the Notification and Excess Energy Charge provisions.

c. Non-compliance: A non-exempt Sub-transmission customer subject to subsection a,

above, who fails to drop load during three rotating outages in a three year period to a level of at least 20% of the customer’s prior billing month’s recorded Maximum Demand averaged over the applicable rotating outage period, is not in compliance with this tariff. The three year period shall commence with the first failure to drop load as specified in this subsection. A customer not in compliance with this condition will be placed at the top of the Sub-transmission customer rotating outage group list and will be expected to comply with subsequent applicable rotating outages. In addition, the customer must select one of the two options below within fifteen days after receiving written notice of non-compliance from SCE. A customer failing to make a selection within the specified time frame will be subject to subsection c. (ii) below.

(i) Subject to Schedule OBMC: The customer shall submit an OBMC Plan, in

accordance with Schedule OBMC, within 30 calendar days of receiving written notice of non-compliance from SCE. Pending the submittal of the OBMC Plan by the customer and pending the review and acceptance of the OBMC Plan by SCE, the customer will remain responsible for dropping load in accordance with the provisions of subsection a, above, including the Notification and Excess Energy charge provisions. If the customer fails to submit an OBMC Plan within 30 days of receiving notice of non-compliance from SCE, or if the customer’s OBMC Plan is not approved by SCE, or if the customer fails to meet the requirements of Schedule OBMC once the OBMC Plan is approved, the customer shall be subject subsection c. (ii), below.



(Continued)




c. Non-compliance: (Continued)

(ii) Installation of Control Equipment. The customer shall be subject to the installation of control equipment at the customer’s expense in accordance with SCE’s Rule 2, Section H, Added Facilities, if such equipment is not currently installed. If such switching capability is installed, SCE will drop the customer’s load for all applicable subsequent rotating outages in accordance with the provisions of subsection b, above. Pending the installation of control equipment, the customer will remain responsible for dropping load in accordance with the provisions of subsection a, above, including the Notification and Excess Energy Charge provisions.

d. Net-Generators






Schedule TOU-GS1-CPPV-2 Sheet 5 TIME-OF-USE GENERAL SERVICE - STATEWIDE PRICING PILOT CRITICAL PEAK PRICING - VARIABLE PERIOD

(Continued)











(Continued)










(Continued)






d. Net-Generators






Schedule AP-I Sheet 4 AGRICULTURAL AND PUMPING - INTERRUPTIBLE

(Continued)


SPECIAL CONDITIONS (Continued) 11. Direct Access: A customer electing Direct Access shall notify its Energy Service Provider

(ESP) and Scheduling Coordinator that it is subject to interruption under this Schedule.

(D)


Schedule TOU-GS-2 Sheet 7 TIME-OF-USE - GENERAL SERVICE - DEMAND METERED

(Continued)
















(T) (L)


Schedule TOU-GS-2 Sheet 8 TIME-OF-USE - GENERAL SERVICE - DEMAND METERED

(Continued)




Non-exempt Sub-transmission customers shall be required to drop their entire electrical load during applicable rotating outages by either (1) implementing the load reduction on their own initiative, in accordance with subsection a, below; or (2) having SCE implement the load reduction through remote-controlled load drop equipment (control equipment) in accordance with subsection b, below. A Sub-transmission customer shall normally be subject to the provisions of subsection a. If SCE approves a customer’s request to have SCE implement the load reduction or if the customer does not did not comply with prior required load reductions, as specified in subsection c, the customer will be subject to the provisions of subsection b. a. Customer-Implemented Load Reduction.






(L) | | | | | | (L) (T) (T)


Schedule PA-1 Sheet 7 POWER - AGRICULTURAL AND PUMPING CONNECTED LOAD BASIS

(Continued)





Non-exempt Sub-transmission customers shall be required to drop their entire electrical load during applicable rotating outages by either (1) implementing the load reduction on their own initiative, in accordance with subsection a, below; or (2) having SCE implement the load reduction through remote-controlled load drop equipment (control equipment) in accordance with subsection b, below. A Sub-transmission customer shall normally be subject to the provisions of subsection a. If SCE approves a customer’s request to have SCE implement the load reduction or if the customer does not comply with prior required load reductions, as specified in subsection c, the customer will be subject to the provisions of subsection b.

(T)


Schedule PA-1 Sheet 8 POWER - AGRICULTURAL AND PUMPING CONNECTED LOAD BASIS

(Continued)











load that is deemed to be equivalent to five percent of the Sub-transmission customer’s prior billing month’s recorded Maximum Demand. This minimum load level is used as a proxy to allow for no-load transformer losses and/or load attributed to minimum grid parallel operation for generators connected under Rule 21.

(T) (T)


Schedule PA-2 Sheet 6 POWER - AGRICULTURAL AND PUMPING DEMAND METERED

(Continued)



above.

Except for the Energy Charge, the charges listed in the Rates section are calculated by multiplying the Total Delivery Service rates and the Generation rates, when applicable, by the billing determinants (e.g., per kilowatt [kW], kilowatthour [kWh], kilovar [kVa] etc.),







b. Direct Access Customers receive Delivery Service from SCE and purchase energy from an Energy Service Provider. The customer’s bill is the sum of the charges for Delivery Service determined as described in this Special Condition except that the DWRBC rate component is subtracted from the Total Delivery Service rates before the billing determinants are multiplied by such resulting Total rates; plus the applicable charges as shown in Schedule DA and subject to applicable discounts or adjustments provided under SCE’s tariff schedules.




(T) (L)


Schedule PA-2 Sheet 7 POWER - AGRICULTURAL AND PUMPING DEMAND METERED

(Continued)




Non-exempt Sub-transmission customers shall be required to drop their entire electrical load during applicable rotating outages by either (1) implementing the load reduction on their own initiative, in accordance with subsection a, below; or (2) having SCE implement the load reduction through remote-controlled load drop equipment (control equipment) in accordance with subsection b, below. A Sub-transmission customer shall normally be subject to the provisions of subsection a. If SCE approves a customer’s request to have SCE implement the load reduction or if the customer does not comply with prior required load reductions, as specified in subsection c, the customer will be subject to the provisions of subsection b. a. Customer-Implemented Load Reduction. (Continued)








(T) (T)


Schedule TOU-GS2-CPPV-1 Sheet 6 TIME-OF-USE-GENERAL SERVICE - STATEWIDE PRICING PILOT CRITICAL PEAK PRICING - VARIABLE PERIOD

(Continued)











(Continued)










(Continued)


SPECIAL CONDITIONS 13. Customers with Service Metered and Delivered at Voltages above 50 kV (Sub-transmission




d. Net-Generators






Schedule TOU-GS2-CPPV-2 Sheet 6 TIME-OF-USE - GENERAL SERVICE - STATEWIDE PRICING PILOT CRITICAL PEAK PRICING - VARIABLE PERIOD

(Continued)











(Continued)










(Continued)






d. Net-Generators






Schedule TOU-GS-2-SOP Sheet 7 TIME-OF-USE - GENERAL SERVICE - SUPER OFF-PEAK - DEMAND METERED

(Continued)
















(T) (L)


Schedule TOU-GS-2-SOP Sheet 8 TIME-OF-USE - GENERAL SERVICE - SUPER OFF-PEAK - DEMAND METERED

(Continued)



customers) Included in Rotating Outages. (Continued) Non-exempt Sub-transmission customers shall be required to drop their entire electrical load during applicable rotating outages by either (1) implementing the load reduction on their own initiative, in accordance with subsection a, below; or (2) having SCE implement the load reduction through remote-controlled load drop equipment (control equipment) in accordance with subsection b, below. A Sub-transmission customer shall normally be subject to the provisions of subsection a. If SCE approves a customer’s request to have SCE implement the load reduction or if the customer does not did not comply with prior required load reductions, as specified in subsection c, the customer will be subject to the provisions of subsection b. a. Customer-Implemented Load Reduction.






(L) | | | | | | (L) (T) (T)

Southern California Edison Revised Cal. PUC Sheet No. 38721-E* Rosemead, California Cancelling Revised Cal. PUC Sheet No. 38550-E*

Schedule PA-RTP Sheet 7 AGRICULTURAL AND PUMPING - LARGE REAL TIME PRICING

(Continued)



above.


The Energy Charge, however, is determined by multiplying the total hourly kWhs by the Total

Delivery Service per kWh rates in each hour and the products are summed to calculate the Delivery Service amount of the Charge. To calculate the Generation amount, SCE determines what portion of the total kWhs is supplied by the Utility Retained Generation (URG) and the Department of Water Resources (DWR). The hourly kWhs supplied by the URG are multiplied by the URG per kWh rates in each hour and the hourly kWhs supplied by the DWR are multiplied by the DWR per kWh rate and the hourly products are summed to arrive at the Generation amount. The Energy Charge is the sum of the Delivery Service amount and the Generation amount.










(T) (L)


Schedule PA-RTP Sheet 8 AGRICULTURAL AND PUMPING - LARGE REAL TIME PRICING

(Continued)




Non-exempt Sub-transmission customers shall be required to drop their entire electrical load during applicable rotating outages by either (1) implementing the load reduction on their own initiative, in accordance with subsection a, below; or (2) having SCE implement the load reduction through remote-controlled load drop equipment (control equipment) in accordance with subsection b, below. A Sub-transmission customer shall normally be subject to the provisions of subsection a. If SCE approves a customer’s request to have SCE implement the load reduction or if the customer does not did not comply with prior required load reductions, as specified in subsection c, the customer will be subject to the provisions of subsection b. a. Customer-Implemented Load Reduction. (Continued)








(L) | | | | | | (L) (T) (T)


Schedule TOU-PA Sheet 7 TIME-OF-USE AGRICULTURAL AND PUMPING

(Continued)



above.








b. Direct Access Customers receive Delivery Service from SCE and purchase energy from an Energy Service Provider. The customer’s bill is the sum of the charges for Delivery Service determined as described in this Special Condition except that the DWRBC rate component is subtracted from the Total Delivery Service rates before the billing determinants are multiplied by such resulting Total rates; plus the applicable charges as shown in Schedule DA and subject to applicable discounts or adjustments provided under SCE’s tariff schedules.

c. Community Choice Aggregation (CCA) customers receive Delivery Service from SCE and purchase energy from their Community Choice Provider (CCP). SCE will read the meters and present the bill for both Delivery and Generation Services to the CCA customer. The customer’s bill is the sum of the charges for Delivery Service as displayed in this Rate Schedule and Generation charges determined by the CCP plus the applicable charges as shown in Schedule CCA-CRS, and subject to applicable discounts or adjustments provided under SCE’s tariff schedules.




(T)


Schedule TOU-PA Sheet 8 TIME-OF-USE AGRICULTURAL AND PUMPING

(Continued)












(T) (T)


Schedule TOU-8-CPP Sheet 11 TIME-OF-USE-GENERAL SERVICE-LARGE CRITICAL PEAK PRICING-VOLUMETRIC CHARGE DISCOUNT-VCD

(Continued)










(T) (T) (T)


Schedule TOU-8-CPP Sheet 14 TIME-OF-USE-GENERAL SERVICE-LARGE CRITICAL PEAK PRICING-VOLUMETRIC CHARGE DISCOUNT-VCD

(Continued)




d. Net-Generators






Schedule TOU-PA-CPP Sheet 9 TIME-OF-USE AGRICULTURAL AND PUMPING CRITICAL PEAK PRICING-VOLUMETRIC CHARGE DISCOUNT-VCD

(Continued)









(T) (T) (T)


Schedule TOU-PA-CPP Sheet 10 TIME-OF-USE AGRICULTURAL AND PUMPING CRITICAL PEAK PRICING-VOLUMETRIC CHARGE DISCOUNT-VCD

(Continued)








(D)

Southern California Edison Revised Cal. PUC Sheet No. 38712-E Rosemead, California Cancelling Original Cal. PUC Sheet No. 38500-E

Schedule TOU-8-CPP-GCCD Sheet 11 TIME-OF-USE-GENERAL SERVICE-LARGE CRITICAL PEAK PRICING - GENERATION CAPACITY CHARGE DISCOUNT

(Continued)


SPECIAL CONDITIONS (Continued) 22. Billing Calculation: A customer’s bill is first calculated according to the total rates and

conditions above. The following adjustments are made depending on the option applicable to the customer.

Except for the Energy Charge, the charges listed in the Rates section are calculated by






Bundled Service Customers receive Delivery Service from SCE and receive supply (Gen)

service from both SCE’s URG and the DWR. The customer’s bill is the sum of the charges for Delivery Service and Gen determined, as described in this Special Condition, and subject to applicable discounts or adjustments provided under SCE’s tariff schedules.




(T)

Southern California Edison Revised Cal. PUC Sheet No. 38713-E Rosemead, California (U 338-E) Cancelling Original Cal. PUC Sheet No. 38501-E

Schedule TOU-8-CPP-GCCD Sheet 12 TIME-OF-USE-GENERAL SERVICE-LARGE CRITICAL PEAK PRICING - GENERATION CAPACITY CHARGE DISCOUNT

(Continued)











(T) (T)


Schedule TOU-8-SOP Sheet 11 TIME-OF-USE - GENERAL SERVICE - LARGE SUPER OFF-PEAK

(Continued)

(Continued) (To be inserted by utility) Issued by (To be inserted by Cal. PUC) Advice 1891-E John R. Fielder Date Filed May 3, 2005 Decision 01-04-006 Senior Vice President Effective Jun 2, 2005 11W16 Resolution















(T) (L)


Schedule TOU-8-SOP Sheet 12 TIME-OF-USE - GENERAL SERVICE - LARGE SUPER OFF-PEAK

(Continued)










(L) | | | | | | (L) (T) (T)


Schedule TOU-PA-5 Sheet 6 TIME-OF-USE AGRICULTURAL AND PUMPING - DEMAND METERED

(Continued)



above.













(T) (L)


Schedule TOU-PA-5 Sheet 7 TIME-OF-USE AGRICULTURAL AND PUMPING - DEMAND METERED

(Continued)





(i) Notification of Required Load Reduction. At the direction of the ISO or when SCE determines there is a need for Rotating Outage, SCE shall notify each Sub-transmission customer in an affected rotating outage group to drop its entire load. Within 30 minutes of such notification, the customer must drop its entire load. The customer shall not return the dropped load to service until 90 minutes after SCE sent the notification to the customer to drop its load, unless SCE notifies the customer that it may return its load to service prior to the expiration of the 90 minutes.







(L) | | | | | | (L) (T) (T)


Schedule TOU-PA-7 Sheet 9 AGRICULTURAL WATER PUMPING - LARGE ALTERNATE POWER SOURCE

(Continued)



above.














(T)


Schedule TOU-PA-7 Sheet 10 AGRICULTURAL WATER PUMPING - LARGE ALTERNATE POWER SOURCE

(Continued)












(T) (T)


Schedule TOU-PA-SOP Sheet 8 TIME-OF-USE - AGRICULTURAL AND PUMPING SUPER OFF-PEAK - DEMAND METERED

(Continued)



above.













(T) (L)


Schedule TOU-PA-SOP Sheet 9 TIME-OF-USE - AGRICULTURAL AND PUMPING SUPER OFF-PEAK - DEMAND METERED

(Continued)












(L) | | | | | | (L) (T) (T)


thru 33922-E*

Schedule DBP Sheet 7 DEMAND BIDDING PROGRAM

(Continued)


SPECIAL CONDITIONS (Continued) 16. Failure to Reduce energy. No penalties will be assessed under this Schedule for a

customer’s failure to comply to reduce energy during a DBP Event.

(D)

Southern California Edison Revised Cal. PUC Sheet No. 38674-E Rosemead, California Cancelling Revised Cal. PUC Sheet No. 38632-

E,37794-E* 37795-E*37796-E*

Schedule DBP Sheet 8 DEMAND BIDDING PROGRAM

(Continued)


SPECIAL CONDITIONS (Continued) 9. Relationship to Other Interruptible/Curtailment Programs. A customer or Aggregated Group

customer, currently taking service under the California Power Authority Demand Reserves Partnership Program (CPA DRP), is not eligible to receive service under this Schedule. A customer or Aggregated Group customer currently taking service under a Critical Peak Pricing (CPP) schedule, Schedule I-6, Schedule TOU-BIP, Schedule AP-I, Schedule OBMC, may be eligible for this program. However, under no circumstances will a customer or Aggregated Group customer taking service under this Schedule concurrently with any of the forementioned applicable Schedules/Programs receive more than one incentive payment for the same interrupted/curtailed load. Should either the ISO or SCE activate a CPP Event, or a notice of Interruption on an Interruptible Schedule for which a DBP customer or Aggregated Group customer participates on, as set forth in the provisions of the applicable rate schedules, during any period that overlaps with the period of a DBP Event under this Schedule, no credits under this Schedule will apply during the period of overlap and all provisions of a customer’s or Aggregated Group customer’s CPP Schedule, or Interruptible Schedule shall prevail. For the duration of this Schedule, a customer or Aggregated Group customer enrolled in this program shall not participate in any ISO Ancillary Services Load Program or pay for performance program.

10. Customer-Owned Electrical Generating Facilities. Customers may achieve energy

reductions by operating back-up or onsite generation. The customer will be solely responsible for meeting all environmental and other regulatory requirements for the operation of such generation.

a. Where customer-owned electrical generating facilities are used to meet a part or all

of the customer’s electrical requirements, service shall be provided concurrently under the terms and conditions of Schedule S and this Schedule. Parallel operation of such generating facilities with SCE’s electrical system is permitted. A Generation Agreement is required for such operation.

b. Customer-owned electrical generating facilities used solely for auxiliary,

emergency, or standby purposes (auxiliary/emergency generating facilities) to serve the customer’s load during a period when SCE’s service is unavailable and when such load is isolated from the service of SCE are not subject to Schedule S. However, upon approval by SCE, momentary parallel operation may be permitted in order for the customer to avoid interruption of load during a DBP Event or to allow the customer to test the auxiliary/emergency generating facilities. A Momentary Parallel Generation Contract is required for this type of service.

11. Failure to Reduce Energy. No penalties will be assessed under this Schedule if a customer or

Aggregated Group fails to comply to reduce energy during a DBP Event.

(D)

Southern California Edison Revised Cal. PUC Sheet No. 38734-E Rosemead, California Cancelling Original Cal. PUC Sheet No. 36247-E thru 36251-E

Schedule FC-NEM Sheet 3 EXPERIMENTAL FUEL CELL NET ENERGY METERING

(Continued)


BILLING (Continued)

1. SCE will present the customer with their annual Relevant Period bill, which will include the current month’s charges in addition to any outstanding accumulated Relevant Period generation charges and shall be due and payable in accordance to SCE’s normal billing cycle.

2. Where a customer’s net generation credits exceed their net generation

charges, during any TOU period, as calculated in the Rates Section of this Schedule, such excess generation credits will be applied to any remaining generation charges in other TOU periods, at the end of a Relevant Period.

c. If a customer terminates service under this Schedule prior to the end of the Relevant

Period Special Condition 3.b shall be invoked.

4. Definitions: The following definitions are applicable to service provided under this Schedule. a. Eligible Fuel Cell Electrical Generating Facility: A generating facility that includes the

following:

1. Integrated powerplant systems containing a stack, tubular array, or other functionally similar configuration used to electrochemically convert fuel to electric energy.

2. An inverter and fuel processing system where necessary.

3. Other plant equipment, including heat recovery equipment, necessary to

support the powerplant’s operation or its energy conversion. b. Date of Final Interconnection: The date SCE provides the customer with SCE’s

written approval to commence parallel operation of the Generating Facility for purposes of participating on this Schedule.

c. Net Energy: The difference between the electricity supplied and/or delivered through

SCE, and the electricity generated by the customer and fed back into SCE’s electric system, measured over the Relevant Period. Thus, where ES is energy supplied and/or delivered by SCE, and EF is energy generated by the customer and fed back into SCE’s system:

Net Energy = ES minus EF

d. Otherwise Applicable Tariff (OAT): The customer’s regularly filed rate schedule under which service is rendered.

e. Relevant Period: A twelve-month period, or portion thereof, commencing on the

anniversary Date of Final Interconnection of the customer’s generator to SCE’s electric system.

(D)

Southern California Edison Revised Cal. PUC Sheet No. 38735-E Rosemead, California (U 338-E) Cancelling Revised Cal. PUC Sheet No. 35572-

E,33923-E* thru 33925-E*

Schedule NEM Sheet 5 NET ENERGY METERING

(Continued)


SPECIAL CONDITIONS (Continued) 5. Definitions: The following definitions are applicable to service provided under this Schedule.

(Continued)

f. Relevant Period: A twelve-month period, or portion thereof, commencing on the anniversary Date of Final Interconnection of the customer’s generator to SCE’s electric system.

(D)


33390-E 33926-27,38636-E

Schedule OBMC Sheet 3 OPTIONAL BINDING MANDATORY CURTAILMENT

(Continued)


SPECIAL CONDITIONS (Continued) 6. Participation in Other Programs: OBMC participants who are the only customers on their

circuit may participate in an SCE administered capacity interruptible program as long as that program requires the reduction of load to a pre-established firm service level (FSL). OBMC participants are eligible to concurrently participate in the Demand Bidding Program (DBP) or the California Power Authority Demand Reserves Partnership Program CPA DRP, but shall not be paid for any load curtailment during periods when an OBMC event overlaps a DBP or CPA DRP Event.

7. Charges for Excess Energy: For each OBMC event during which the customer fails to curtail

load to its required level, as measured in 30 minute periods, and hence incurs Excess Energy, the applicable $/kWh penalty in accordance with Special Condition 9 shall be added to the customer’s billing as otherwise provided in this Schedule.

8. Excess Energy: The number of kWh consumed in each 30 minute period in an OBMC event

that exceeds the required circuit load curtailment, as measured for each 30 minute period of an OBMC event shall be considered Excess Energy. Excess Energy shall be measured using the baseline measurement in accordance with Special Condition 5.b.

9. Excess Energy Charges: Penalties equal to $6/kWh shall apply to all excess energy, for each

OBMC event. 10. Cost of Equipment: Communication, metering, or any other equipment required to participate

in this program is the sole responsibility of the customer(s). 11. Failure to Comply: Failure to curtail circuit load to within 5 percent of the required amount, as

measured during the entire duration of an OBMC event, on two occasions in any one year shall result in the customer(s) termination on the program and the customer shall be prohibited from participating in an OBMC program for five years.

12. Agreements. All applicable agreements, including an Optional Binding Mandatory

Curtailment Agreement Between Customer and Southern California Edison Company (SCE), Form 14-740, must be signed in order to receive service under this Schedule.

(D)

Southern California Edison Revised Cal. PUC Sheet No. 38737-E Rosemead, California Cancelling Revised Cal. PUC Sheet No. 38225-E

TABLE OF CONTENTS Sheet 1


Cal. P.U.C. Sheet No.

TITLE PAGE ..................................................................................................................................11431-E TABLE OF CONTENTS - RATE SCHEDULES ..... 38737-38226-38657-38738-38739-38740-38741-E TABLE OF CONTENTS - LIST OF CONTRACTS AND DEVIATIONS ......................................38741-E TABLE OF CONTENTS - RULES ................................................................................................38662-E TABLE OF CONTENTS - BASELINE REGIONS ........................................................................38663-E TABLE OF CONTENTS - SAMPLE FORMS .....................38664-36548-37804-36443-35196-36853-E

.......................................................................................................................................36854-E PRELIMINARY STATEMENT:

A. Territory Served ...............................................................................................................22909-E B. Description of Service ......................................................................................................22909-E C. Procedure to Obtain Service ...........................................................................................22909-E D. Establishment of Credit and Deposits .............................................................................22909-E E. General............................................................................................ 22909-27629-2763038292-E F. Symbols ............................................................................................................................27630-E G. Gross Revenue Sharing Mechanism ......... 26584-26585-26586-26587-27195-27196-27197-E

........................................................................................................27198-27199-27200-27201-E H. Baseline Service ............................................................... 11457-31455-11880-11881-31679-E I. NOT IN USE................................................................................................................................ -E J. Employee-Related Balancing Account.............................................................................36295-E K. Nuclear Decommissioning Adjustment Mechanism ............................................36582-36583-E L. Performance-Based Ratemaking Exclusions Distribution Adjustment Mechanism ..............................................................................................3443738293-36584-36585-36297-E M. Income Tax Component of Contributions ...........................................................34071-27632-E N. Memorandum Accounts....... 21344-37769-37098-37828-37770-31526-36784-36506-34416-E

36507-34418-36526-37771-37772-37773-37774-37775-37776-27542-26595-27643-27644-E 27645-27646-27647-27648-27649-27650-27651-27652-27653-27654-27655-27656-31327-E 26596-36797-21960-34441-34442-22546-27658-23703-27829-29774-29775-29776-29777-E 27663-36590-36591-30057-30058-30059-30060-26484-26485-23212-28280-24197-29470-E

26486-29471-24199-29472-23221-23222-23223-24200-26487-29473-23227-37099-28282-E 36592-24477-24812-223,80-28283-22621-36593-24272-27015-30234-27476-26007-26757-E 26996-26735-33597-27500-27424-27425-27477-29778-28408-29789-29488-36594-35952-E .................................. 36595-32988-33085-36596-34420-31665-31936-32936-33531-37830-E

O. California Alternative Rates for Energy (CARE) Adjustment Clause ..................................................................................34705-36471-36472-36473-3659838294-E

P. Optional Pricing Adjustment Clause (OPAC).................... 27670-27671-27672-27673-27674-E

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(Continued)


RATES SCHEDULES Schedule Cal. P.U.C. No. Title of Sheet No.

GENERAL SERVICE/INDUSTRIAL

AEDR Attraction Economic Development Rate ................ 34770-34771-30885-34772-34773-E EEDR Expansion Economic Development Rate .............. 34774-34775-34776-34777-34778-E GS-1 General Service - Non Demand ..................38324-38325-38326-38327-38328-38329-E .....................................................................................................................38330-38331-E GS-2 General Service - Demand .............. 38332-38333-38334-38335-38336-38337-38338-E ..............................................................................................38339-38340-38341-38342-E GS2-TOU-CPP General Service-Time-Of-Use-Demand Metered Critical Peak Pricing .............38343-38344-36529-38345-36531-38346-38347-38348-38349-38350-38351-E GS-APS General Service - Automatic Powershift, Non-Demand................ 38352-28753-38679-E ..............................................................................................38354-38355-38356-38357-E

GS-APS-E General Service - Automatic Powershift – Enhanced ........38358-28758-38680-38360-E ......................................................................................................... 38361-38362-38363-E I-6 Time-of-Use, General Service - Large - Interruptible ................... 38364-38365-38366-E ................................................38367-34812-38368-38369-38370-38371-38372-38681-E ..............................................................................................38374-38375-38376-38377-E

I-6-BIP General Service – Large – Base Interruptible Program .....37778-37779-37780-37781-E ......................................................................................................... 37782-37783-37784-E REDR Retention Economic Development Rate ................ 34825-34826-34827-34828-34829-E RTP-2 General Service - Large, Real Time Pricing Test.......................... 38378-38379-38380-E .................................... 38381-38382-38383-38384-38385-38682-38683-38388-38389-E RTP-2-I General Service - Large, Real Time Pricing Test, Interruptible ........................ 38390-38391-38392-38393-38394-38395-38396-38397-38398-38399-E .......................................................................38400-38684-38402-38403-38404-38405-E RTP-3 General Service - Large, Real Time Pricing ......................28525-28526-23838-28527-E ......................................................................................................... 28899-26127-28302-E RTP-3-GS General Service Real Time Pricing.. 28529-23844-27105-28530-28900-26129-28304-E SSGDR Simplified Self-Generation Deferral Rate............................34855-27708-30917-34856-E TOU-BIP Time-Of-Use-General Service Base Interruptible Program......................38406-38407-E ................................................................................. 38408-38685-38410-38411-38412-E TOU-EV-3 General Service Time-Of-Use Electric Vehicle Charging ............. 38413-34858-34859-E TOU-EV-4 General Service - Time-Of-Use Electric Vehicle Charging........... 38414-38415-38416-E ....................................................................................................................38417-38418-E TOU-GS-1 General Service - Non Demand..................38419-38420-38421-38686-38687-38424-E ....................................................................................................................38425-38426-E TOU-GS1-CPPV-1 Experimental Time-of-Use General Service Critical Peak Pricing Variable Period .... .........................................38427-33456-36349-38428-38688-38689-38690-38691-E TOU-GS1-CPPV-2 Experimental Time-of-Use General Service Critical Peak Pricing Variable Period .... .........................................38429-33461-36350-38430-38692-38693-38694-38695-E TOU-GS1-SPP-1 Experimental Time-of-Use General Service Statewide Pricing Pilot............................ .................................................................................................. 37864-33466-36351-E TOU-GS1-SPP-2 Experimental Time-of-Use General Service Statewide Pricing Pilot............................ .................................................................................................. 37865-33470-36352-E

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(Continued)


RATE SCHEDULES (Continued)

Schedule Cal. P.U.C. No. Title of Sheet Sheet No.

TOU-GS-2 General Service - Time-of-Use - Demand Metered ..........38431-38432-34882-38433-E .......................................................... 38434-38435-38696-38697-38438-38439-38440-E TOU-GS2-CPPV-1 Experimental Time-of-Use General Service Critical Peak Pricing Variable Period .... ............................. 38441-33474-36353-38442-38443-38698-38699-38700-38701-E TOU-GS2-CPPV-2 Experimental Time-of-Use General Service Critical Peak Pricing Variable Period .... ............................. 38444-33480-36354-38445-38446-38702-38703-38704-38705-E TOU-GS2-SPP-1 Experimental Time-of-Use General Service Statewide Pricing Pilot............................ ........................................................................... 37691-33486-36356-34898-34602-E TOU-GS2-SPP-2 Experimental Time-of-Use General Service Statewide Pricing Pilot............................ ........................................................................... 37692-33491-36357-34901-34604-E TOU-GS-2-SOP Time-of-Use, General Service - Demand Metered ........38447-38448-38449-38450-E .......................................................... 38451-38452-38706-38707-38455-38456-38457-E TOU-8 General Service - Large ..............38458-38459-38460-38461-38462-38463-38464-E ...........................38465-38466-38467-38468-38469-38708-38471-38472-38473-ETOU-8-BU Time-of-Use, General Service, Large, Back-Up Service ................38474-38475-38476-E ............................................................34931-34932-38477-38709-33846-33847-33848-E TOU-8-CPP Time-Of-Use, General Service – Large Critical Peak Pricing ............... 38478-38479-38480-38481-38482-38483-36534-38484-38485-38486-E .....................................................................................38710-38488-38489-38711-ETOU-8-CPP-GCCD Time-of-Use-General Service-Large Critical Peak Pricing- Generation Capacity Charge Discount.................................. 38490-38491-38492-E ............... 38493-38494-38495-38496-38497-38498-38499-38712-38713-38502-E ............... 38503-38504-38505-38506-38507-38508-38509-38510-38511-38512-E ............................................................. 38513-38514-38515-38516-38517-38518-ETOU-8-CR-1 General Service - Large Contract Rate 1, Incremental Sales..............29025-23906-E ...............................................................33273-33274-33850-33851-33852-33853ETOU-8-RTP Time-of-Use, Real Time On-Peak Demand Charge, General Service, Large ....37883-37884-37885-37886-34942-34943-34944-34945-34946-34947-34948-E .........................................................................34949-34950-33854-33855-33856-ETOU-8-SOP Time-of-Use, General Service - Large, Super Off-Peak .......... 37887-37888-37889-E ....23929-34956-34957-34958-34959-34960-34961-38714-38715-33863-33864-E ....................................................................................................................... 33865-ETOU-8-SOP-I Time-of-Use, General Service - Large - Super Off-Peak – Interruptible ............... 37890-37891-37892-34969-34970-35815-35816-35817-35818-35819-E .........................................................................25820-25821-23870-23871-33872-ETOU-8-SOP-RTP Time-of-Use, Real Time On-Peak Demand Charge, General Service, Large, Super Off-Peak ............37893-37894-37895-37896-34984-34985-34986-E ...........................34987-34988-34989-34990-34991-33876-33877-33878-33879-E

AGRICULTURAL/PUMPING AP-I Agricultural and Pumping - Interruptible 38519-38520-38521-38716-38523-38524-E ....................................................................................................................... 38525-EPA-1 Power - Agricultural and Pumping (Connected Load Basis)................38526-35003-E ...................................... 38527-38528-38529-38530-38717-38718-38533-38534-EPA-2 Power - Agricultural and Pumping (Demand Basis)................. 38535-38536-38537-E ............................................................. 38538-38539-38719-38720-38542-38543-E

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(Continued)



Schedule Cal. P.U.C. No. Title of Sheet No.

AGRICULTURAL/PUMPING (Continued)

PA-RTP Agricultural and Pumping - Large, Real Time Pricing ............ 38544-38545-38546-E .....................................38547-38548-35026-38549-38721-38722-38552-38553-E TOU-PA Time-of-Use, Agricultural and Pumping.......................38554-38555-35035-38556-E ............................................................38557-38558-38723-38724-38561-38562-E TOU-PA-CPP Time-of-Use, Agricultural and Pumping Critical Peak Pricing .....................................38563-38564-38565-36536-36537-38566-38567-38568-E ...................................................................................38725-38726-38571-38572-E TOU-PA-3 Time-of-use, Agricultural and Pumping ........... 37904-37905-35045-35046-34047-E ....................................................................... 35048-35049-33899-33900-33901-E TOU-PA-4 Time-of-Use, Agricultural and Pumping, Demand Metered... 37906-37907-35055-E ................................................ 35056-35057-35058-35059-33902-33903-33904-E TOU-PA-5 Time-of-Use, Agricultural and Pumping, Demand Metered ...............38573-38574-E .................................................... 38575-38576-38577-38727-38728-38580-38581-E TOU-PA-6 Time-of-Use, Agricultural and Pumping, Large, Alternate Power Source ............................. 37910-37911-35074-35075-35076-35077-33908-33909-33910-E TOU-PA-7 Agricultural Water Pumping - Large Alternate Power Source ................. 38582-38583-38584-38585-38586-38587-38588-38589-38729-38730-E ..............................................................................................................38592-38593-E TOU-PA-SOP Time-of-Use, Agricultural and Pumping, Super Off-Peak ......38594-38595-38596-38597-38598-38599-38600-38731-38732-38603-38604-E TOU-PA-SOP-I Time-of-Use, Agricultural and Pumping, Super Off-Peak Interruptible ............................. 37918-35105-35106-35835-36724-35837-33917-33918-33919-E

STREET & AREA LIGHTING/TRAFFIC CONTROL

AL-1 Outdoor Area Lighting Service ...........................................................37919-35114-E AL-2 Outdoor Area Lighting Service - Metered..........................................38605-38606-E DWL Residential Walkway Lighting .............38607-38608-35119-35120-35121-38609-E LS-1 Lighting - Street and Highway (Utility-owned System) ......................38610-38611-E .................................................... 35125-35126-35127-35128-35272-35130-38612-E LS-2 Lighting - Street and Highway (Customer-owned Installation) ................. 38613-38614-38615-35135-35136-35137-35138-35139-35140-38616-E ..........................................................................................................................38617-E LS-3 Lighting - Street and Highway (Customer-owned Installation) .......................................................................................38618-35144-38619-38620-E OL-1 Outdoor Area Lighting Service....................................38621-35148-35149-38622-E TC-1 Traffic Control Service .......................................................................38623-35152-E

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(Continued)



Schedule Cal. P.U.C. No. Title of Sheet Sheet No.

OTHER

20/20 California Rebate Program..................................................................37785-37786-E BG-NEM Experimental Biogas Net Energy Metering.......33175-33176-33177-33178-33179-E BSC-IMO Bundled Service Customer-Interval Meter Ownership............25699-25700-25701-E CC-DSF Customer Choice - Discretionary Service Fees .......... 26202-25172-26204-26205-E ............................ 25174-34383-31849-26209-31850-25179-25180-25181-25182-E CGDL-CRS Customer Generation Departing Load – Cost Responsibility Surcharge ......37289-E ........................................................................... 33577-33578-33579-33580-36954-E CTCE-IWD Competition Transition Charge Exemptions Irrigation/Water Districts

..............................................................................................................24129-24130-E DA-CRS Direct Access – Cost Responsibility Surcharge ..........37288-38624-36735-36736-E DAC-VA-NDSF Direct Access Customer Value Added Non-Discretionary Service Fees ......25713-E DA-RCSC Direct Access Revenue Cycle Services Credits ..........38625-38626-38627-38628-E

.................................................................................................. 38629-38630-38631-E DA-SF Direct Access Service Fee .............................................................................36737-E DBP Demand Bidding Program.....................37787-37788-37789-37790-37791-38674-E DL-NBC Departing Load - Nonbypassable Charges ........................................37290-36955-E ESP-DSF Energy Service Provider - Discretionary Service Fees .......... 26215-26216-26217-E ............................. 32532-26219-26220-32533-31852-26223-26224-26225-26226-E ESP-NDSF Energy Service Provider - Non Discretionary Service Fees...............25139-25140-E ESP-VA-NDSF Energy Service Provider Value Added Non-Discretionary Service Fees ......25714-E FC-NEM Fuel Cell Electrical Generating Facility Net Energy Metering & .......... 36245-36245E Interconnection Agreement .............................. 38734-36248-36249-36250-36251-E GS-FR Experimental General Service - Flat Rate .............................. 26863-26864-26865-E GSN EnvestSCE Equipment Service .....................................17880-17881-17882-17883-E NEM Net Energy Metering.......35568-36433-38633-38634-38735-33923-33924-33925-E OBMC Optional Binding Mandatory Curtailment ......... 38635-29799-38736-33390-33926-E ..............................................................................................................33927-38636-E PC-TBS Procurement Charge Transitional Bundled Service ...37128-36230-34096-34097-E ..........................................................................................................................33392-E PVS Experimental Photovoltaic Service......................................................19770-19771-E PVS-2 On-Grid Photovoltaic Service .............................................................19518-19519-E PX Power Exchange....................................26998-26999-28351-28352-27485-27486-E RF-E Surcharge to Fund Public Utilities Commission Reimbursement Fee ...........35933-E RRB Rate Reduction Bonds - Bill Credit and FTAC....................................38637-38638-E S Standby ........................................................................38639-38640-38641-38642-E .................................................... 38643-38644-38645-38646-38647-38648-38649-E SE Service Establishment Charge .......................................................................36739-E SLRP Scheduled Load Reduction Program............... 31314-29111-29802-29113-29803-E .......................................................................................33393-33929-33930-33931-E UCLT Utility-Controlled Load Tests ..........................................................................11737-E VPRC Voluntary Power Reduction Credit ................... 26738-26739-26740-26741-26742-E WTR Wireless Technology Rate ...........................................38650-36767-36768-36773-E

LIST OF CONTRACTS AND DEVIATIONS LIST OF CONTRACTS AND DEVIATIONS .......... 31106-31079-36202-35452-28418-36203-24944-E

..................................... 17894-17895-17896-17897-17898-27171-18103-33545-36572-26971-E

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March 14, 2006

California Public Utilities Commission 505 Van Ness Avenue, Room 4005 San Francisco, CA 94102

Attn: Jerry Royer Energy Division

Re: Substitute Sheets for Advice 1891-E, and 1862-E

Dear Mr. Royer: Enclosed are an original and four copies of Attachment A, Table of Contents Sheet Nos. 38741-E*, and Substitute Sheet Nos. 38674-E and 37793-E**. These Substitute Sheets are necessary due to Advice Letters becoming effective out of order. Therefore, the Cal PUC Cancelling Sheet Nos. have been modified to reflect the appropriate information. Sheet No. 38733-E is being withdrawn and replaced by Sheet No. 38674-E. These changes ensure that all approved revisions are contained in the affected tariff sheets. Please include the enclosed sheets in your master Advice 1891-E, and 1862-E file. If you have any questions, please contact Ruby Diaz at (626) 302-2010.

Sincerely,

Enclosures 1891-E, 1862-ESub.doc

public utilities commission of the state of … · p.o. box 800 2244 walnut grove ave. rosemead,...

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