10. Rehearing and Judicial Review

This decision construes, applies, implements, and interprets the provisions of ABX1 1 (Chapter 4 of the Statutes of 2001-02 First Extraordinary Session). Therefore, § 1731(c) (applications for rehearing are due within 10 days after the date of issuance of the order or decision) and § 1768 (procedures applicable to judicial review) are applicable.

Findings of Fact

1. The record of the public participation hearings confirms that past electric rate increases and the prospect of more increases are deeply impacting the citizens, businesses, and economy of SDG&E's service territory, and that additional rate increases will inflict additional hardship upon the region. Accordingly, we intend to approve only those rate increases that are required to maintain system reliability and that are required as a matter of law.

2. DWR is authorized to procure power, and to determine and recover its revenue requirement for power that it sells to retail end use customers served by electrical corporations.

3. DWR is currently procuring and providing power to SDG&E's retail end use customers.

4. In our companion order on the DWR revenue requirement issued today in A.00-11-038, et al. (Ordering Paragraph 3 of D.01-09-___), we directed SDG&E to begin disbursements of proceeds to DWR on a monthly basis using a system average charge of 9.02 cents per kWh for each kWh sold by DWR to SDG&E's customers.

5. Taking into account Ordering Paragraph 3 of D.01-09-___, the current rate of SDG&E's disbursements to DWR, and the forecast that 58% of SDG&E's total bundled retail sales will be supplied by DWR, a system average rate increase of 1.46 cents per kWh is required to implement the allocated DWR revenue requirement designated for SDG&E by Ordering Paragraph 3 of D.01-09-___.

6. To the extent that the actual percentage of DWR sales to SDG&E's retail end use customers is either less than or exceeds the 58% forecast percentage of DWR sales to those customers for any month, the customer's bill for that month will not exactly provide the imputed utility rate for the kWhs the utility provides.

7. It is not our intent that the utility ultimately recover either more or less than the imputed utility rate for the kWhs it provides.

8. Our objectives in this decision include establishing rates that will ensure that the DWR revenue requirement is collected from SDG&E's ratepayers in accordance with D.01-09-___; observing and giving effect to the second sentence of § 332.1(f); observing and promoting principles of equity in the allocation of revenue responsibility and rate design; promoting energy conservation in the establishment of rate structures; and observing and recognizing legal requirements and practical constraints.

9. The constraints on obtaining and analyzing evidence concerning the underlying cost components limit our ability to apply cost-based principles in assigning revenue responsibility to customer classes and in designing individual rate structures.

10. FEA's cost-based revenue allocation methodology is complex, has not been adequately examined in this expedited proceeding, and requires acceptance of untested assumptions about costs underlying the DWR revenue requirement.

11. Given the unpredictability of the current flawed electric market, it is reasonable to simplify cost allocation methods.

12. Subsidizing agricultural customers by capping average rate increases at 20% for TOU rates and 15% for non-TOU is consistent with our adopted policy in D.01-05-064; there is no record evidence justifying a different policy on agricultural subsidies in this case; and extending such subsidies to SDG&E's customers is consistent with legislative intent in § 332.1(f).

13. Water Code § 80110 provides that residential customer usage up to 130% of baseline quantities is exempt from increases in electricity charges, and proposals to exempt residential CARE and medical baseline customers from rate increases are uncontested.

14. Allocating shortfalls from the CARE and medical baseline exemptions and the agricultural rate caps to all other customers on an equal cents per kWh basis is uncontested and is generally consistent with our allocation of shortfalls in D.01-06-064.

15. The 1/3 residential; 1/3 commercial; 1/3 industrial allocation method adopted in Decision 01-05-064 does not work for SDG&E, which has a combined commercial/industrial classification and a much different mix of customer classes than either PG&E or Edison.

16. Allocating the revenue shortfall from the 130% of baseline exemption only to non-exempt residential consumption would create severe rate spikes, and set an unnecessarily high conservation price signal which would apply to less than 15% of total forecast sales.

17. It is equitable to allocate the shortfall from the 130% of baseline exemption on an equal cents per kWh basis to all non-exempt customers.

18. There is no evidence supporting tiered rate design for non-residential rates.

19. No party opposes SDG&E's proposed adoption of the 5-tier rate design structure that was adopted in D.01-05-064 for PG&E and Edison.

20. Tiered residential rates are appropriate both because of their conservation effects and because of the statutory exemption of consumption up to 130% of baseline quantities.

21. The design of rates requires the exercise of judgment, and cannot rely solely on mathematical formulas. We have exercised our institutional judgment and experience in designing a tiered residential rate structure that balances the need to provide conservation signals, the need to collect the revenue requirement allocated to the residential class, and the need to prevent undue bill impacts.

22. We intend to preserve the five-tier residential rate structure until we have had an opportunity to more fully consider all aspects of SDG&E's rate design in a proceeding dedicated to that purpose.

23. Due to billing system constraints, SDG&E may not be able to implement the medical baseline rate exemption immediately.

24. If the commodity rates for residential TOU rate schedules are not tiered like the non-TOU residential rate schedules, customers will have an incentive to switch rate schedules simply to avoid an increase.

25. The large customer rates adopted today are consistent with the requirement of § 332.1(f) that we consider adjustments to the initial frozen rate of 6.5 cents per kWh based on consideration of comparable energy components of rates for comparable customer classes served by PG&E and Edison.

26. Renaming the ERCRSA as the ERSA, and recording large customer shortfalls and overcollections in the ERSA separately from the small customer shortfall, will maintain consistency with current tariffs and facilitate the transfer of any applicable TCBA overcollections to the ERSA to offset the required retroactive credits to February 7, 2001.

27. The primary purpose of the ERSA mechanism is to record SDG&E's costs for URG, ancillary services and ISO costs, and related revenues, refunds, and authorized balancing account transfers. DWR-related revenues collected by SDG&E on behalf of DWR shall be segregated from SDG&E's revenues.

28. The voluntary program for large customers adopted by D.00-12-033 is unnecessary with implementation of the frozen rate component under ABX1 43, does not work as intended due to SDG&E's inability to true-up accounts to reflect DWR costs, and has no customers currently enrolled.

29. It is of critical importance to implement the DWR increases on a timely basis to provide assurance to DWR that it will receive its identified revenue requirement, thereby maintaining the ability of the State of California to procure power on behalf of retail end use customers.

30. The circumstances leading to our decision today include the following: we must act expeditiously to increase rates in order to implement the DWR revenue requirement to protect the ability of DWR to procure electricity; we are implementing an urgency statute enacted "to safeguard economic viability of the communities in the San Diego region;" we are implementing rate designs to promote demand reduction in order to mitigate the frequency and duration of rolling blackouts throughout California; and on January 17, 2001 Governor Gray Davis declared a state of emergency in connection with the electric crisis. These circumstances, and the fact that we did not receive the latest revised DWR revenue requirement request until August 7, 2001, constitute an unforeseen emergency.

31. Parties were provided notice of the expedited schedule, and no objections to the reduced comment period were raised. We therefore assume that all parties have stipulated to a reduction of the 30-day periods specified in § 311(d).

32. In this order, we are not approving the individual components underlying SDG&E's calculations, including t hose with respect to URG, ISO charges, and sales forecasts.

Conclusions of Law

1. In accordance with Water Code §§ 80110 and 80134, and our decision today in A.00-11-038 et al. regarding the DWR revenue requirement, the portion of the DWR revenue requirement attributable to SDG&E should be included in total electric rates for SDG&E.

2. The Commission is obligated by law to implement the DWR revenue requirement and to establish rates for SDG&E's customers, payable to DWR, that will provide for the collection of the DWR revenue requirement that is attributable to SDG&E's customers.

3. Pursuant to Water Code §§ 80016, 80110, and 80134, and our general obligation, under the Public Utilities Act, to ensure the provision of safe and reliable service by the utilities we regulate, we should order rate increases necessary for the collection of the allocated DWR revenue requirement.

4. The rate increases adopted herein are intended to provide for the collection of the DWR revenue requirement that is attributable to SDG&E's retail end use customers as set forth in D.01-09-___

5. Allocating responsibility for the total revenue requirement, including the revenue requirement associated with the DWR revenue requirement implemented by this decision, to customer classes and designing rates to collect the revenue requirement is an exercise of the Commission's ratemaking authority.

6. This decision does not approve the individual components underlying SDG&E's calculations and assumptions with respect to URG and ISO costs for any purpose unrelated to this decision, and does not prejudge our deliberations in A.00-11-038, et al.

7. SDG&E should be authorized and directed to establish a balancing account mechanism to ensure that the utility recovers neither more nor less than its imputed utility rate.

8. The § 332.1(b) ceiling for SDG&E's small customers does not prohibit assigning rate increases that result from implementing DWR's revenue requirement to small customers, and the Section 332.1(f) requirement for a frozen rate for large customers does not prohibit assigning rate increases that result from implementing DWR's revenue requirement to large customers.

9. In applying our institutional expertise and experience as well as our understanding of law and policy to make hard choices based on the law, California energy policy and the record before us, it is reasonable to expect that we will reach conclusions similar to those reached in D.01-05-064 on issues having the same or similar policy and factual contexts.

10. While it is generally appropriate to allocate revenue responsibility among customer classes on the basis of cost causation principles, an equal cents per kWh allocation of revenue responsibility is appropriate under the present circumstances, and should therefore be adopted.

11. Consistent with D.01-05-064, we should approve caps on increases for agricultural rates of 20% for TOU rates and 15% for non-TOU rates.

12. Consistent with D.01-05-064, the revenue shortfall from the 130% of baseline exemption should be allocated on an equal cents per kWh basis to all non-exempt customers.

13. Consistent with D.01-05-064, we should adopt a five-tier residential rate structure for SDG&E.

14. SDG&E's proposal to implement the medical baseline exemption in phases should be adopted.

15. SDG&E's proposal to rename the ERCRSA as the ERSA and to record the large customer shortfall in the ERSA should be adopted. Any large customer shortfalls or overcollections should be recorded separately from the small customer shortfall in the ERSA. Any large customer revenues received for URG costs and ancillary services and ISO-related costs should be recorded in the large customer portion of the ERSA.

16. SDG&E should be authorized to transfer any undercollection or overcollection from the memorandum account approved in D.01-05-060 to the large customer portion of the ERSA, and to terminate the memorandum account.

17. The voluntary bill stabilization program for large customers adopted by D.00-12-033 should be terminated.

18. The rate increases that result from implementing the DWR revenue requirement at issue in this decision should not be made applicable to direct access customers at this time.

19. This order should be effective today so that these rate changes may be implemented expeditiously.

20. CARE customers and medical baseline customers should be exempt from the rate increase approved in this order.

21. The revenue shortfall from the exemptions for CARE customers and medical baseline customers should be shared by all other customers on an equal cents per kWh basis.

22. Consistent with D.01-05-064, the rate increases related to the DWR revenue requirement should not be applied directly to direct access customers.

O R D E R

IT IS ORDERED that:

1. The electric rates charged by San Diego Gas & Electric Company (SDG&E) shall be increased by 1.46 cents per kilowatt-hour (kWh) on a system-average basis to provide for collection of the California Department of Water Resources (DWR) revenue requirement attributable to SDG&E's customers, consistent with our companion order on the DWR revenue requirement issued in Application 00-11-038, et al. Such rates shall be set in accordance with the revenue allocation and rate design determinations set forth in the foregoing discussion, findings, and conclusions.

2. Within five days of the effective date of this decision, SDG&E shall file an advice letter to implement new rates pursuant to Ordering Paragraph 1. The advice letter shall be effective as soon as practicable on or after September 15, 2001, and in any event not later than October 1, 2001, subject to Energy Division determining that it is in compliance with this decision. The rates filed in the advice letter shall reflect the rates shown in Appendices B and C of this decision, subject to adjustment for the medical baseline allowance. SDG&E shall include with its advice letter detailed and complete work papers showing the revenue allocation and rate design calculations underlying the new rates for each rate schedule. On the same day that SDG&E files its advice letter, it shall serve electronic copies of the workpapers on Energy Division and all active parties in this phase of the proceeding. Specifically, SDG&E shall file tariffs that effect the following principles:

a. Utility Retained Generation shall be assigned to all customer classes. The system average rate increase is 1.46 cents/kWh, and rates shall be set using annual sales to bundled service customers of 16,828,800 Megawatt-hours, consistent with Exhibits 9 and 26. The revenue increase shall be allocated on an equal cents per kWh basis before revenue shortfalls are taken into account.

b. CARE-eligible customers and non-CARE medical baseline customers are exempt from the rate increase adopted in this Order. The revenue shortfall resulting from exempting these customers shall be allocated to all other customers, but not to residential consumption below 130% of baseline, on an equal cents per kWh basis.

c. The rates attached to this Order do not reflect exemption of non-CARE medical baseline customers from the rate increases adopted herein. In its compliance advice letter, SDG&E shall reflect the exemption of non-CARE medical baseline customers. SDG&E shall show in the workpapers supporting its compliance advice letter how the revenue allocation and rate design was modified to reflect the exemption of these customers.

d. Increases in agricultural rates shall be capped at 20% for TOU rates and 15% for non-TOU rates. Any revenue shortfall created by capping agricultural rates shall be allocated to all non-exempt customers, but not to residential consumption below 130% of baseline, on an equal cents per kWh basis.

e. The revenue shortfall from exempting residential consumption below 130% of baseline shall be allocated to all non-exempt customer classes.

f. SDG&E shall reflect a 5 tier-rate residential rate design with incremental block tiers with the following tiers:

a. Tier 1 Up to the baseline amount

b. Tier 2 From 100% - up to 130% of baseline

c. Tier 3 From 130% - up to 200% of baseline

d. Tier 4 From 200% - up to 300% of baseline

e. Tier 5 In excess of 300% of baseline

g. SDG&E shall design residential rates such that rates for Tiers 3, 4, and 5 closely approximate those shown in Appendix B. The percent difference between the Tier 4 rate as compared to the Tier 2 rate shall be approximately twice the percent difference between the Tier 3 rate as compared to the Tier 2 rate. The Tier 5 rate shall be designed such that it recovers the residual revenue after setting rates for Tiers 3 and 4.


h. Residential TOU rates shall be tiered using the same tiered rates applied for the non-TOU residential schedules, leaving the TOU signals embedded in the transmission and distribution portion of these residential rates.

i. For small commercial customers with seasonal designation (Schedule A), 70% of the revenue increase shall be allocated to the summer period and 30% to the winter period.


j. For non-residential TOU customers and residential electric vehicle TOU schedules, the revenue increase shall be allocated across all time periods. The summer on-peak period rate increase shall be 2 cents per kWh higher than the average rate increase for the tariff schedule, and the remaining revenue increase shall be allocated on an equal cents per kWh to the semi- and off-peak periods.

3. If SDG&E is unable to implement the medical baseline rate exemption on the effective date of the rate increases, SDG&E shall: (a) implement this rate exemption no later than 30 days following the effective date of the rate increases, (b) apply on December 2001 bills a credit to medical baseline customers for any amount previously billed in excess of applicable rates adopted herein, and (c) notify medical baseline customers no later than October 1, 2001 that they will receive a credit for any amount billed in excess of the applicable rates adopted in this decision.

4. SDG&E is authorized and directed to establish a balancing account mechanism and shall book into the balancing account the difference between the imputed utility rate based on today's decision and the effective utility rate it has billed, multiplied by the number of kWhs billed at that effective utility rate. The balancing account shall be trued up during the next update proceeding for DWR scheduled for February 1, 2002.

5. SDG&E is authorized to rename the Energy Rate Ceiling Revenue Shortfall Account as the Energy Revenue Shortfall Account (ERSA) and to establish separate recording of revenues and expenses for small customers and large customers in accordance with the foregoing discussion. SDG&E is further authorized to transfer any balance in the memorandum account established pursuant to D.01-05-060 to the large customer portion of the ERSA, and to thereafter terminate the memorandum account.

6. The voluntary bill stabilization program established by D.00-12-033 shall be terminated by SDG&E effective with the effective date of the Advice Letter filing made pursuant to this decision.

7. This proceeding shall remain open.

This order is effective today.

Dated , at San Francisco, California.

APPENDIX A

List of Appearances

Applicant: Thomas Brill and Keith W. Melville, Attorneys at Law, for San Diego Gas & Electric Company.

Interested Parties: Goodin, MacBride, Squeri, Ritchie & Day LLP, by Jeanne M. Bennett, for Enron Energy Services, Inc.; Peter Bray, for the New Power Company; Brubaker & Associates, by Maurice Brubaker, for Brubaker & Associates; Christine Costa, Attorney at Law, for Southern California Edison Company; Sam De Frawi, for Navy Rate Intervention; Arter & Hadden, LLP, by Daniel W. Douglass, Attorney at Law, for Alliance for Retail Energy Markets; Norman J. Furuta, Attorney at Law, for Federal Executive Agencies; Adams, Broadwell, Joseph & Cardozo, by Marc D. Joseph, Attorney at Law, for Coalition of California Utility Employees (CUE); Luce, Forward, Hamilton & Scripps, LLP, by John W. Leslie, Attorney at Law, for Shell Energy Services, LP & The Alliance for Retail Energy Markets; Ronald Liebert, Attorney at Law, for California Farm Bureau Federation; Warren Savage, for Santee Chamber of Commerce; Christopher J. Warner, Attorney at Law, for Pacific Gas and Electric Company; James Weil, for Aglet Consumer Alliance; Bernardo R. Garcia, for Utility Workers Union of America, Bernardo Garcia, et al.; Robert Finkelstein, Attorney at Law, for The Utility Reform Network; Richard J. McCann, for M. Cubed; Anderson & Poole, P.C., by Edward G. Poole, Attorney at Law, for CA Independent Petroleum Association, Independent Oil Producers Agency, Western Manufactured Housing Community Association; Jennifer Tachera, Attorney at Law, for the California Energy Commission; and Darwin Farrar, Attorney at Law, for the Office of Ratepayer Advocates.

Intervenor: Michael Shames, Attorney at Law, for Utility Consumers' Action Network.

Protestants: Harold Ball, for Helix Water District & County Water Authority; Sara Steck Myers, Attorney at Law, for the City of San Diego and Frederick M. Ortlieb, Deputy City Attorney, for the City of San Diego.

(END OF APPENDIX A)

Schedules DR, DR-LI, DM, DS, DT, DT-RV, and D-SMF
NON-CARE
Usage Charges
Summer Period
Baseline	1479.46	12.83	189.76		189.76	12.83
Baseline to 130% of BL	339.04	15.28	51.81		51.81	15.28
130% - 200% of BL	523.97	15.28	80.07	4.84	84.90	16.20
200% - 300% of BL	369.86	15.28	56.52	6.78	63.30	17.11
Over 300% of BL	369.86	15.28	56.52	12.60	69.12	18.69
Minimum Bill	2.65	NA	0.18
Winter Period
Baseline	1365.65	12.83	175.16		175.16	12.83
Baseline to 130% of BL	312.96	14.57	45.60		45.60	14.57
130% - 200% of BL	483.67	14.57	70.47	4.26	74.73	15.45
200% - 300% of BL	341.41	14.57	49.74	5.97	55.71	16.32
Over 300% of BL	341.41	14.57	49.74	12.12	61.86	18.12
Minimum Bill	2.50	NA	0.17
NON-CARE SUB-TOTAL	5927.31	13.93	825.72	46.57	872.29	14.72	5.64%
Baseline CARE	169.90	10.90	18.52	0.00	18.52	10.90
Baseline to 130% of BL CARE	26.70	12.99	3.47	0.00	3.47	12.99
130% - 200% of BL CARE	29.13	12.99	3.78	0.00	3.78	12.99
200% - 300% of BL	12.14	12.99	1.58	0.00	1.58	12.99
Over 300% of BL	4.85	12.99	0.63	0.00	0.63	12.99
Minimum Bill CARE	0.10	NA	0.01	NA	0.01	6.59
Baseline CARE	158.53	10.90	17.28	0.00	17.28	10.90
Baseline to 130% of BL CARE	24.91	12.38	3.08	0.00	3.08	12.38
130% - 200% of BL CARE	27.18	12.38	3.37	0.00	3.37	12.38
200% - 300% of BL	11.32	12.38	1.40	0.00	1.40	12.38
Over 300% of BL	4.53	12.38	0.56	0.00	0.56	12.38
Minimum Bill CARE	0.09	NA	0.01	NA	0.01	6.59
CARE SUB-TOTAL	469.19	11.44	53.68	0.00	53.68	11.44	0.00%
Total for Schedules DR, DR-LI, DM, DS, DT, DT-RV, and D-SMF	6396.50	13.75	879.40	46.57	925.97	14.48	5.30%
Schedule DR-TOU
Usage Charges
T&D Charges
On-Peak Energy: Summer	0.29	8.88	0.03	0.00	0.03	8.88
Off-Peak Energy: Summer	1.99	7.18	0.14	0.00	0.14	7.18
On-Peak Energy: Winter	0.28	7.38	0.02	0.00	0.02	7.38
Off-Peak Energy: Winter	2.01	7.18	0.14	0.00	0.14	7.18
Baseline Adjustment Credit	2.30	-1.05	-0.02	NA	-0.02	-1.05
Commodity Charges
Baseline	2.20	6.50	0.14	0.00	0.14	6.50
Baseline to 130% of BL	0.50	6.50	0.03	0.00	0.03	6.50
130% - 200% of BL	0.80	6.50	0.05	0.01	0.06	7.42
Over 200% of BL	0.50	6.50	0.03	0.01	0.04	8.33
Over 300% of BL	0.50	6.50	0.03	0.02	0.05	9.91
Total for Schedule DR-TOU	4.57	13.18	0.60	0.03	0.63	13.79	4.67%
Schedule DR-TOU-2
Usage Charges
T&D TOU Charges
On-Peak Energy: Summer	4.13	8.67	0.36	0.00	0.36	8.67
Off-Peak Energy: Summer	20.33	7.13	1.45	0.00	1.45	7.13
On-Peak Energy: Winter	3.49	7.32	0.26	0.00	0.26	7.32
Off-Peak Energy: Winter	20.98	7.13	1.50	0.00	1.50	7.13
Commodity Charges
Baseline	23.49	6.50	1.53	0.00	1.53	6.50
Baseline to 130% of BL	5.38	6.50	0.35	0.00	0.35	6.50
130% - 200% of BL	8.32	6.50	0.54	0.08	0.62	7.42
Over 200% of BL	5.87	6.50	0.38	0.11	0.49	8.33
Over 300% of BL	5.87	6.50	0.38	0.20	0.58	9.91
Total for Schedule DR-TOU-2	48.93	13.78	6.74	0.38	7.13	14.56	5.70%
Schedules EV-TOU/EV-TOU-2/EV-TOU-3
Usage Charges
On-Peak Energy: Summer	0.02	15.17	0.00	0.00	0.00	19.09
Off-Peak Energy: Summer	0.05	13.66	0.01	0.00	0.01	15.19
Super Off-Peak Energy: Summer	0.04	13.45	0.01	0.00	0.01	14.99
On-Peak Energy: Winter	0.02	13.88	0.00	0.00	0.00	17.79
Off-Peak Energy: Winter	0.05	13.66	0.01	0.00	0.01	15.19
Super Off-Peak Energy: Summer	0.04	13.45	0.01	0.00	0.01	14.99
Total for Schedules EV-TOU/EV-TOU-2/EV-TOU-3	0.22	13.72	0.03	0.00	0.03	15.64	13.96%
RESIDENTIAL TOTAL	6450.43	13.75	886.81	46.99	933.80	14.48	5.30%
Small Commercial
Schedule A
Fixed Charges - Basic Service Fees		0.48	10.01	0.00	10.01
Usage Charges
Summer Secondary	914.09	14.03	128.28	27.75	156.03	17.07
Summer Primary	2.08	13.60	0.28	0.06	0.35	16.63
Winter Secondary	1156.07	13.19	152.50	11.89	164.39	14.22
Winter Primary	2.64	12.84	0.34	0.03	0.37	13.86
Total for Schedule A	2074.87	14.04	291.41	39.73	331.14	15.96	13.63%
Schedule A-TC
Fixed Charges - Basic Service Fees		1.09	0.77	0.00	0.77
Usage Charges	70.59	11.00	7.76	1.35	9.11	12.91
Total for Schedule A-TC	70.59	12.09	8.53	1.35	9.89	14.00	15.84%
SMALL COMMERCIAL TOTAL	2145.46	13.48	299.95	41.08	341.03	15.90	17.94%
Schedule AD
Fixed Charges
Basic Service Fees		0.12	0.08	0.00	0.08
Demand Charges-Secondary		5.00	3.13	0.00	3.13
Demand Charges-Primary		2.22	0.03	0.00	0.03
Usage Charges
Secondary	62.53	7.89	4.93	1.20	6.13	9.80
Primary	1.39	7.85	0.11	0.03	0.14	9.77
Total for Schedule AD	63.93	12.94	8.27	1.22	9.50	14.86	14.80%
Schedule A-TOU
Fixed Charges-Basic Service Fees		0.16	0.19	0.00	0.19
Usage Charges
On-Peak Energy: Summer	12.95	14.11	1.83	0.38	2.21	17.05
On-Peak Energy: Winter	6.85	13.06	0.89	0.16	1.06	15.44
Semi-Peak	40.79	12.04	4.91	0.71	5.62	13.77
Off-Peak	53.34	11.99	6.40	0.93	7.32	13.73
Total A-TOU	113.92	12.47	14.21	2.18	16.39	14.39	15.35%
Schedules AL-TOU/AO-TOU/NJ
Fixed Charges
Basic Service Fees
Secondary		0.11	1.62	0.00	1.62
Primary		0.00	0.00	0.00	0.00
Secondary Substation		0.00	0.00	0.00	0.00
Primary Substation		0.00	0.00	0.00	0.00
Transmission		0.00	0.00	0.00	0.00
Demand Charges
Secondary		2.86	42.85	0.00	42.85
Primary		2.39	5.55	0.00	5.55
Secondary Substation		0.93	0.67	0.00	0.67
Primary Substation		0.62	1.84	0.00	1.84
Transmission		0.59	0.47	0.00	0.47
Usage Charges
On-Peak Summer
Secondary	174.37	8.04	14.02	6.83	20.85	11.96
Primary	24.65	8.00	1.97	0.96	2.94	11.92
Secondary Substation	8.37	7.57	0.63	0.33	0.96	11.48
Primary Substation	31.04	7.53	2.34	1.22	3.55	11.44
Transmission	7.74	7.52	0.58	0.30	0.88	11.44
Semi-Peak Summer
Secondary	190.22	7.77	14.77	2.28	17.05	8.96
Primary	29.81	7.74	2.31	0.38	2.69	9.02
Secondary Substation	9.13	7.29	0.67	0.11	0.78	8.49
Primary Substation	37.63	7.27	2.74	0.48	3.22	8.56
Transmission	9.56	7.27	0.69	0.13	0.82	8.61
Off-Peak Summer
Secondary	295.66	7.49	22.14	3.54	25.68	8.69
Primary	47.85	7.48	3.58	0.61	4.19	8.76
Secondary Substation	14.19	7.21	1.02	0.17	1.19	8.41
Primary Substation	61.27	7.20	4.41	0.79	5.20	8.48
Transmission	17.42	7.20	1.25	0.23	1.49	8.54
On-Peak Winter
Secondary	85.63	7.84	6.72	3.35	10.07	11.76
Primary	12.25	7.82	0.96	0.48	1.44	11.73
Secondary Substation	4.11	7.46	0.31	0.16	0.47	11.38
Primary Substation	15.55	7.42	1.15	0.61	1.76	11.34
Transmission	4.06	7.42	0.30	0.16	0.46	11.34
Semi-Peak Winter
Secondary	369.32	7.68	28.36	6.23	34.59	9.37
Primary	55.72	7.66	4.27	0.95	5.22	9.36
Secondary Substation	17.73	7.30	1.29	0.30	1.59	8.98
Primary Substation	70.42	7.27	5.12	1.20	6.32	8.98
Transmission	17.56	7.27	1.28	0.30	1.58	8.98
Off-Peak Winter
Secondary	385.37	7.49	28.88	6.50	35.38	9.18
Primary	62.24	7.48	4.66	1.06	5.72	9.19
Secondary Substation	18.50	7.21	1.33	0.31	1.65	8.90
Primary Substation	79.41	7.20	5.72	1.36	7.07	8.91
Transmission	22.56	7.20	1.62	0.39	2.01	8.91
Total Schedule AL-TOU/AO-TOU/NJ	2179.31	10.01	218.08	41.73	259.81	11.92	19.13%
Schedule AY-TOU
Fixed Charges
Basic Service Fees
Secondary		0.17	0.45		0.45
Primary		0.06	0.01		0.01
Transmission		0.08	0.00		0.00
Demand Charges
Secondary		3.80	10.32		10.32
Primary		3.11	0.39		0.39
Transmission		0.58	0.00		0.00
Usage Charges
On-Peak Energy
Secondary	54.59	8.68	4.74	2.14	6.88	12.59
Primary	2.27	8.63	0.20	0.09	0.28	12.54
Transmission	0.09	7.50	0.01	0.00	0.01	11.41
Semi-Peak Energy
Secondary	120.72	8.04	9.71	1.70	11.41	9.45
Primary	5.52	8.01	0.44	0.08	0.52	9.48
Transmission	0.20	7.28	0.01	0.00	0.02	8.85
Off-Peak Energy
Secondary	96.33	7.80	7.52	1.36	8.88	9.21
Primary	4.71	7.78	0.37	0.07	0.44	9.26
Transmission	0.31	7.21	0.02	0.00	0.03	8.77
Total AY-TOU	284.75	12.00	34.18	5.45	39.63	13.92	15.95%
MEDIUM/LARGE COMMERCIAL (AB 265) TOTAL	2641.90	10.40	274.74	50.59	325.33	12.31	18.41%
Schedule LS-1
Fixed Charges		14.70	3.43		3.43
Usage Charges	23.32	6.50	1.52	0.45	1.96	8.41
	23.32	21.20	4.94	0.45	5.39	23.12	9.03%
Schedule LS-2
Fixed Charges		2.94	1.54		1.54
Usage Charges	52.50	6.50	3.41	1.01	4.42	8.41
Total for Schedule LS-2	52.50	9.44	4.96	1.01	5.96	11.35	20.28%
Schedule LS-3
Fixed Charges		0.00	0.00		0.00
Usage Charges	3.98	8.17	0.32	0.08	0.40	10.09
Total for Schedule LS-3	3.98	8.17	0.32	0.08	0.40	10.09	23.43%
Schedule OL-1
Fixed Charges		11.90	0.99		0.99
Usage Charges	8.28	6.50	0.54	0.16	0.70	8.41
Total for Schedule OL-1	8.28	18.40	1.52	0.16	1.68	20.32	10.40%
Schedule DWL
Fixed Charges		4.25	0.28		0.28
Usage Charges	6.63	6.50	0.43	0.13	0.56	8.41
Total for Schedule DWL	6.63	10.75	0.71	0.13	0.84	12.67	17.81%
STREET LIGHTING TOTAL	94.71	13.16	12.46	1.81	14.28	15.07	14.55%
AVERAGE INCREASE SMALL	11332.50	13.01	1473.96	140.47	1614.43	14.25	9.53%

(END OF APPENDIX B)

Schedule AD
Fixed Charges
Basic Service Fees		0.11	0.04		0.04
Demand Charges-Secondary		4.50	1.79		1.79
Demand Charges-Primary		2.00	0.02		0.02
Usage Charges
Secondary	39.72	7.89	3.13	0.76	3.89	9.80
Primary	0.89	7.85	0.07	0.02	0.09	9.77
Total for Schedule AD	40.61	12.44	5.05	0.78	5.83	14.35	15.40%
Schedules AL-TOU/AO-TOU/NJ
Fixed Charges
Basic Service Fees
Secondary		0.13	3.83	0.00	3.83	0.13
Primary		0.03	0.14	0.00	0.14	0.00
Secondary Substation		1.77	2.58	0.00	2.58	0.08
Primary Substation		0.87	5.22	0.00	5.22	0.17
Transmission		0.01	0.02	0.00	0.02	0.00
Demand Charges
Secondary		2.86	86.76	0.00	86.76	2.86
Primary		0.02	11.24	0.00	11.24	0.02
Secondary Substation		0.01	1.35	0.00	1.35	0.01
Primary Substation		0.01	3.73	0.00	3.73	0.01
Transmission		0.01	0.94	0.00	0.94	0.01
Usage Charges
On-Peak Summer
Secondary	353.06	8.04	28.39	13.82	42.21	11.96
Primary	49.90	8.00	3.99	1.95	5.95	11.92
Secondary Substation	16.95	7.57	1.28	0.66	1.95	11.48
Primary Substation	62.85	7.53	4.73	2.46	7.19	11.44
Transmission	15.67	7.52	1.18	0.61	1.79	11.44
Semi-Peak Summer
Secondary	385.15	7.77	29.91	4.61	34.52	8.96
Primary	60.36	7.74	4.67	0.77	5.44	9.02
Secondary Substation	18.49	7.29	1.35	0.22	1.57	8.49
Primary Substation	76.18	7.27	5.54	0.98	6.52	8.56
Transmission	19.36	7.27	1.41	0.26	1.67	8.61
Off-Peak Summer
Secondary	598.64	7.49	44.83	7.17	51.99	8.69
Primary	96.89	7.48	7.24	1.24	8.48	8.76
Secondary Substation	28.73	7.21	2.07	0.34	2.42	8.41
Primary Substation	124.06	7.20	8.93	1.60	10.52	8.48
Transmission	35.26	7.20	2.54	0.47	3.01	8.54
On-Peak Winter
Secondary	173.38	7.84	13.60	6.79	20.39	11.76
Primary	24.81	7.82	1.94	0.97	2.91	11.73
Secondary Substation	8.32	7.46	0.62	0.33	0.95	11.38
Primary Substation	31.48	7.42	2.34	1.23	3.57	11.34
Transmission	8.21	7.42	0.61	0.32	0.93	11.34
Semi-Peak Winter
Secondary	747.78	7.68	57.41	12.62	70.04	9.37
Primary	112.82	7.66	8.64	1.93	10.56	9.36
Secondary Substation	35.89	7.30	2.62	0.61	3.22	8.98
Primary Substation	142.58	7.27	10.37	2.43	12.80	8.98
Transmission	35.56	7.27	2.58	0.61	3.19	8.98
Off-Peak Winter
Secondary	780.28	7.49	58.47	13.17	71.64	9.18
Primary	126.02	7.48	9.43	2.15	11.58	9.19
Secondary Substation	37.45	7.21	2.70	0.63	3.33	8.90
Primary Substation	160.78	7.20	11.58	2.74	14.32	8.91
Transmission	45.68	7.20	3.29	0.78	4.07	8.91
Total Schedule AL-TOU/AO-TOU/NJ	4412.59	10.20	450.06	84.49	534.55	12.11	18.77%
Schedule AY-TOU
Fixed Charges
Basic Service Fees
Secondary		0.17	0.32	0.00	0.32	0.17
Primary		0.06	0.01	0.00	0.01	0.06
Transmission		0.08	0.00	0.00	0.00	0.08
Demand Charges
Secondary		3.80	7.42	0.00	7.42	3.80
Primary		3.11	0.28	0.00	0.28	3.11
Transmission		0.58	0.00	0.00	0.00	0.58
Usage Charges
On-Peak Energy
Secondary	39.24	8.68	3.41	1.54	4.94	12.59
Primary	1.63	8.63	0.14	0.06	0.20	12.54
Transmission	0.06	7.50	0.00	0.00	0.01	11.41
Semi-Peak Energy
Secondary	86.78	8.04	6.98	1.23	8.20	9.45
Primary	3.97	8.01	0.32	0.06	0.38	9.48
Transmission	0.15	7.28	0.01	0.00	0.01	8.85
Off-Peak Energy
Secondary	69.25	7.80	5.40	0.98	6.38	9.21
Primary	3.39	7.78	0.26	0.05	0.31	9.26
Transmission	0.22	7.21	0.02	0.00	0.02	8.77
Total AY-TOU	204.68	12.00	24.57	3.92	28.49	13.92	15.95%
Schedule AV-1
Fixed Charges
Basic Service Fees
Secondary		0.09	0.03		0.03	0.09
Primary		0.04	0.01		0.01	0.04
Primary Substation		0.00	0.00		0.00	0.00
Transmission		0.12	0.01		0.01	0.12
Demand Charges
Secondary		0.46	0.16		0.15	0.46
Primary		0.62	0.11		0.11	0.62
Primary Substation		0.00	0.00		0.00	0.00
Transmission		1.25	0.13		0.13	1.25
Usage Charges
Signal Period 1G
Secondary	0.02	160.33	0.03	0.00	0.03	160.33
Primary	0.00	151.38	0.00	0.00	0.00	151.38
Primary Substation	0.00	80.72	0.00	0.00	0.00	80.72
Transmission	0.00	80.23	0.00	0.00	0.00	80.23
Semi-Peak Energy
Secondary	22.46	8.91	2.00	0.43	2.43	10.82
Primary	12.71	8.63	1.10	0.24	1.34	10.55
Primary Substation	0.00	7.39	0.00	0.00	0.00	9.31
Transmission	6.83	7.39	0.50	0.13	0.64	9.30
Off-Peak Energy
Secondary	11.98	8.12	0.97	0.23	1.20	10.04
Primary	5.22	7.98	0.42	0.10	0.52	9.90
Primary Substation	0.00	7.23	0.00	0.00	0.00	9.14
Transmission	3.63	7.22	0.26	0.07	0.33	9.14
Total Schedule AV-1	62.86	9.13	5.74	1.20	6.93	11.02	20.65%
Schedule AV-2
Fixed Charges
Basic Service Fees
Secondary		0.17	0.00	0.00	0.00	0.17
Primary		0.01	0.00	0.00	0.00	0.01
Primary Substation		0.00	0.00	0.00	0.00	0.00
Transmission		0.00	0.00	0.00	0.00	0.00
Demand Charges
Secondary		6.00	0.09	0.00	0.09	6.00
Primary		4.67	1.27	0.00	1.27	4.67
Primary Substation		0.00	0.00	0.00	0.00	0.00
Transmission		0.00	0.00	0.00	0.00	0.00
Usage Charges
Signal Period 1G
Secondary	0.00	144.52	0.00	0.00	0.00	144.52
Primary	0.07	136.22	0.10	0.00	0.10	136.22
Primary Substation	0.00	65.86	0.00	0.00	0.00	65.86
Transmission	0.00	65.47	0.00	0.00	0.00	65.47
Signal Period 2G
Secondary	0.01	23.65	0.00	0.00	0.00	23.65
Primary	0.13	22.65	0.03	0.00	0.03	22.65
Primary Substation	0.00	14.68	0.00	0.00	0.00	14.68
Transmission	0.00	14.62	0.00	0.00	0.00	14.62
Semi-Peak Energy
Secondary	1.17	8.55	0.10	0.02	0.12	10.47
Primary	13.21	8.34	1.10	0.25	1.36	10.26
Primary Substation	0.00	7.31	0.00	0.00	0.00	8.97
Transmission	0.00	7.31	0.00	0.00	0.00	8.96
Off-Peak Energy
Secondary	0.25	8.17	0.02	0.00	0.02	10.09
Primary	13.78	8.02	1.10	0.26	1.37	9.93
Primary Substation	0.00	7.23	0.00	0.00	0.00	8.94
Transmission	0.00	7.22	0.00	0.00	0.00	8.93
Total Schedule AV-2	28.62	13.33	3.82	0.54	4.36	15.23	14.25%
Schedule RTP-2
Fixed Charges
Basic Service Fees
Secondary		0.11	0.01	0.00	0.01	0.11
Primary		0.05	0.01	0.00	0.01	0.05
Primary Substation		0.00	0.00	0.00	0.00	0.00
Transmission		0.00	0.00	0.00	0.00	0.00
Demand Charges
Secondary		6.37	0.66	0.00	0.66	6.37
Primary		2.91	0.48	0.00	0.48	2.91
Primary Substation		0.00	0.00	0.00	0.00	0.00
Transmission		0.00	0.00	0.00	0.00	0.00
Usage Charges
RTP Period
Secondary	0.08	28.27	0.02	0.00	0.02	28.27
Primary	0.08	26.21	0.02	0.00	0.02	26.21
Primary Substation	0.00	23.51	0.00	0.00	0.00	23.51
Transmission	0.00	23.40	0.00	0.00	0.00	23.40
On-Peak Summer
Secondary	1.49	8.18	0.12	0.06	0.18	12.09
Primary	1.91	8.15	0.16	0.07	0.23	12.06
Primary Substation	0.00	7.68	0.00	0.00	0.00	11.36
Transmission	0.00	7.68	0.00	0.00	0.00	11.36
Semi-Peak Summer
Secondary	1.69	7.81	0.13	0.02	0.15	8.72
Primary	2.79	7.78	0.22	0.03	0.25	8.97
Primary Substation	0.00	7.31	0.00	0.00	0.00	8.30
Transmission	0.00	7.31	0.00	0.00	0.00	8.29
Off-Peak Summer
Secondary	1.29	7.53	0.10	0.01	0.11	8.44
Primary	2.48	7.52	0.19	0.03	0.22	8.71
Primary Substation	0.00	7.24	0.00	0.00	0.00	8.25
Transmission	0.00	7.24	0.00	0.00	0.00	8.25
On-Peak Winter
Secondary	0.53	8.32	0.04	0.02	0.06	12.24
Primary	0.75	8.27	0.06	0.03	0.09	12.18
Primary Substation	0.00	7.87	0.00	0.00	0.00	11.59
Transmission	0.00	7.87	0.00	0.00	0.00	11.58
Semi-Peak Winter
Secondary	3.53	7.72	0.27	0.06	0.33	9.43
Primary	5.03	7.70	0.39	0.09	0.47	9.43
Primary Substation	0.00	7.31	0.00	0.00	0.00	8.95
Transmission	0.00	7.31	0.00	0.00	0.00	8.94
Off-Peak Winter
Secondary	1.68	7.54	0.13	0.03	0.16	9.25
Primary	3.46	7.52	0.26	0.06	0.32	9.26
Primary Substation	0.00	7.24	0.00	0.00	0.00	8.90
Transmission	0.00	7.24	0.00	0.00	0.00	8.90
Total Schedule RTP-2	26.81	12.17	3.26	0.51	3.77	14.08	15.63%
Schedule A6-TOU
Fixed Charges
Basic Service Fees
Primary		0.09	0.00		0.00	0.09
Primary Substation		0.88	0.46		0.46	0.88
Transmission		0.01	0.04		0.04	0.01
Demand Charges
Primary		3.37	0.16		0.16	3.37
Primary Substation		0.75	0.40		0.40	0.75
Transmission		0.64	2.82		2.82	0.64
Usage Charges
On-Peak Summer
Primary	0.46	7.88	0.04	0.02	0.05	11.79
Primary Substation	5.08	7.40	0.38	0.20	0.58	11.31
Transmission	42.09	7.40	3.11	1.65	4.76	11.31
Semi-Peak Summer
Primary	0.61	7.63	0.05	0.01	0.06	8.98
Primary Substation	6.75	7.16	0.48	0.09	0.57	8.51
Transmission	53.32	7.16	3.82	0.72	4.54	8.51
Off-Peak Summer
Primary	1.04	7.37	0.08	0.01	0.09	8.72
Primary Substation	11.41	7.09	0.81	0.15	0.96	8.44
Transmission	97.30	7.09	6.90	1.32	8.22	8.44
On-Peak Winter
Primary	0.21	7.69	0.02	0.01	0.02	11.61
Primary Substation	2.30	7.30	0.17	0.09	0.26	11.22
Transmission	20.55	7.30	1.50	0.80	2.31	11.22
Semi-Peak Winter
Primary	1.20	7.55	0.09	0.02	0.11	9.29
Primary Substation	13.15	7.16	0.94	0.23	1.17	8.91
Transmission	97.76	7.16	7.00	1.69	8.69	8.89
Off-Peak Winter
Primary	1.29	7.38	0.10	0.02	0.12	9.12
Primary Substation	14.14	7.09	1.00	0.25	1.25	8.84
Transmission	126.95	7.09	9.00	2.20	11.20	8.82
Total Schedule A6-TOU	495.62	7.94	39.36	9.49	48.85	9.86	24.11%
Schedule PA-T-1
Fixed Charges
Basic Service Fees		0.18	0.24	0.00	0.24	0.18
Demand Charges
Secondary		1.02	1.28		1.28	1.02
Primary		0.43	0.02		0.02	0.43
Transmission		0.00	0.00		0.00	0.00
Usage Charges
On-Peak
Secondary	8.78	8.14	0.72	0.34	1.06	12.06
Primary	0.29	8.11	0.02	0.01	0.04	12.03
Transmission	0.00	7.65	0.00	0.00	0.00	11.33
Semi-Peak
Secondary	41.38	7.82	3.24	0.73	3.97	9.59
Primary	1.41	7.80	0.11	0.02	0.13	9.55
Transmission	0.00	7.45	0.00	0.00	0.00	9.12
Off-Peak
Secondary	75.42	7.54	5.68	1.33	7.01	9.30
Primary	2.21	7.52	0.17	0.04	0.20	9.28
Transmission	0.00	7.25	0.00	0.00	0.00	8.94
Total for Schedule PA-T-1	129.49	8.86	11.47	2.48	13.95	10.78	21.60%
TOU COMMERCIAL/INDUSTRIAL (ABX1 43) TOTAL	5401.26	10.06	543.33	103.41	646.72	11.97	19.03%
Schedule PA
Fixed Charges Basic Service Fees		0.50	0.48	0.00	0.48	0.50
Usage Charges	94.55	12.74	12.05	1.81	13.86	14.66
Total for Schedule PA	94.55	13.24	12.52	1.81	14.33	15.16	14.46%
Schedule PA-TOU
Fixed Charges-Basic Service Fees		0.45	0.00	0.00	0.00	0.45
Usage Charges
On-Peak	0.14	13.85	0.02	0.00	0.02	15.76
Off-Peak	0.39	12.92	0.05	0.01	0.06	14.84
Total for Schedule PA-TOU	0.53	13.61	0.07	0.01	0.08	15.53	14.06%
AGRICULTURAL TOTAL	95.08	13.25	12.60	1.82	14.42	15.16	14.45%
LARGE CUSTOMER TOTAL	5496.34	10.11	555.92	105.24	661.13	12.03	18.93%
SYSTEM TOTAL	16828.85	12.06	2029.88	245.71	2275.59	13.52	12.10%