San-Diego-Gas-
Content
Revised
San Diego Gas & Electric Company San Diego, California
Cal. P.U.C. Sheet No. Cal. P.U.C. Sheet No.
20504-E 20258-E Sheet 1
Canceling
Revised
SCHEDULE AL-TOU
GENERAL SERVICE - TIME METERED
APPLICABILITY
Applicable to all metered non-residential customers whose monthly maximum demand equals, exceeds, or is expected to equal or exceed 20 kW. This schedule is not applicable to residential customers, except for those three-phase residential customers taking service on this schedule as of April 12, 2007 who may remain on this schedule while service continues in their name at the same service address. Those three-phase residential customers remaining on this schedule who choose to switch to a residential rate schedule may not return to this schedule. This schedule is optionally available to common use and metered non-residential customers whose Monthly Maximum Demand is less than 20 kW. Any customer whose Maximum Monthly Demand has fallen below 20 kW for three consecutive months may, at their option, elect to continue service under this schedule or be served under any other applicable schedule. This schedule is the utility's standard tariff for commercial and industrial customers with a Monthly Maximum Demand equaling or exceeding 20 kW. Non-profit group living facilities taking service under this schedule may be eligible for a 20% California Alternate Rates for Energy (CARE) discount on their bill, if such facilities qualify to receive service under the terms and conditions of Schedule E-CARE. Agricultural Employee Housing Facilities, as defined in Schedule E-CARE, may qualify for a 20% CARE discount on the bill if all eligibility criteria set forth in Form 142-4032 or Form 142-4035 is met. TERRITORY Within the entire territory served by the Utility.
RATES
Description – AL-TOU Transm Basic Service Fees ($/month) 0-500 kW Secondary Primary Secondary Substation Primary Substation Transmission > 500 kW Secondary Primary Secondary Substation Primary Substation Transmission > 12 MW Secondary Substation Primary Substation Trans. Multiple Bus Distance Adjust. Fee Secondary - OH Secondary - UG Primary - OH Primary - UG Distr PPP ND CTC RS TRAC UDC Total
T
$58.22 58.22 16,630.12 16,630.12 84.67 232.87 232.87 16,630.12 16,630.12 338.77 26,185.08 26,185.08 3,000.00 1.23 3.17 1.22 3.13
I I I I I I I I I I I I
$58.22 58.22 16,630.12 16,630.12 84.67 232.87 232.87 16,630.12 16,630.12 338.77 26,185.08 26,185.08 3,000.00 1.23 3.17 1.22 3.13
I I I I I I I I I I I I
1C20
(Continued) Issued by
Date Filed Effective Resolution No.
Mar 28, 2008 May 1, 2008
Advice Ltr. No. Decision No.
1978-E
08-02-034
Lee Schavrien
Senior Vice President Regulatory Affairs
Revised
San Diego Gas & Electric Company San Diego, California
Cal. P.U.C. Sheet No. Cal. P.U.C. Sheet No.
22271-E 22167-E Sheet 2
Canceling
Revised
SCHEDULE AL-TOU
GENERAL SERVICE - TIME METERED
RATES (Continued)
Description – AL-TOU Demand Charges ($/kW) Non-Coincident Secondary Primary Secondary Substation Primary Substation Transmission Maximum On-Peak Summer Secondary Primary Secondary Substation Primary Substation Transmission Winter Secondary Primary Secondary Substation Primary Substation Transmission Power Factor ($/kvar) Secondary Primary Secondary Substation Primary Substation Transmission Transm Distr PPP ND CTC RS TRAC UDC Total
4.88 4.71 4.88 4.71 4.66
R R R R R
8.81 8.67
0.34 0.33 0.34 0.33 0.33
14.03 13.71 5.22 5.04 4.99
R R R R R
1.05 1.01 1.05 1.01 1.00 0.23 0.22 0.23 0.22 0.22
R R R R R R R R R R
5.76 6.51 1.34 0.33 0.25 4.91 5.04 0.20 0.06 0.05
0.54 0.51 0.54 0.25 0.25 0.08 0.08 0.08 0.05 0.05
7.35 8.03 2.93 1.59 1.50 5.22 5.34 0.51 0.33 0.32
R R R R R R R R R R
0.25 0.25 0.25 0.25
0.25 0.25 0.25 0.25
.
2C7
(Continued) Issued by
Date Filed Effective Resolution No.
Mar 11, 2011 Apr 1, 2011
Advice Ltr. No. Decision No.
2237-E
Lee Schavrien
Senior Vice President Regulatory Affairs
Revised
San Diego Gas & Electric Company San Diego, California
Cal. P.U.C. Sheet No. Cal. P.U.C. Sheet No.
22272-E 22168-E Sheet 3
Canceling
Revised
SCHEDULE AL-TOU
GENERAL SERVICE - TIME METERED RATES (Continued)
Description – AL-TOU Energy Charges ($/kWh) On-Peak - Summer Secondary Primary Secondary Substation Primary Substation Transmission Semi-Peak – Summer Secondary Primary Secondary Substation Primary Substation Transmission Off-Peak – Summer Secondary Primary Secondary Substation Primary Substation Transmission On-Peak – Winter Secondary Primary Secondary Substation Primary Substation Transmission Semi-Peak – Winter Secondary Primary Secondary Substation Primary Substation Transmission Off-Peak - Winter Secondary Primary Secondary Substation Primary Substation Transmission 0.00018 0.00018 0.00018 0.00018 0.00018 0.00018 0.00018 0.00018 0.00018 0.00018 0.00018 0.00018 0.00018 0.00018 0.00018 0.00018 0.00018 0.00018 0.00018 0.00018 0.00018 0.00018 0.00018 0.00018 0.00018 0.00018 0.00018 0.00018 0.00018 0.00018 I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I 0.00508 0.00290 0.00230 0.00041 0.00047 0.00296 0.00170 0.00134 0.00024 0.00028 0.00235 0.00135 0.00106 0.00019 0.00022 0.00425 0.00241 0.00192 0.00034 0.00039 0.00296 0.00170 0.00134 0.00024 0.00028 0.00235 0.00135 0.00106 0.00020 0.00022 0.00614 0.00614 0.00614 0.00614 0.00614 0.00614 0.00614 0.00614 0.00614 0.00614 0.00614 0.00614 0.00614 0.00614 0.00614 0.00614 0.00614 0.00614 0.00614 0.00614 0.00614 0.00614 0.00614 0.00614 0.00614 0.00614 0.00614 0.00614 0.00614 0.00614 0.00040 0.00040 0.00040 0.00040 0.00040 0.00040 0.00040 0.00040 0.00040 0.00040 0.00040 0.00040 0.00040 0.00040 0.00040 0.00040 0.00040 0.00040 0.00040 0.00040 0.00040 0.00040 0.00040 0.00040 0.00040 0.00040 0.00040 0.00040 0.00040 0.00040 0.00130 0.00127 0.00130 0.00123 0.00123 0.00076 0.00076 0.00076 0.00071 0.00071 0.00061 0.00059 0.00061 0.00059 0.00059 0.00110 0.00107 0.00110 0.00102 0.00102 0.00076 0.00076 0.00076 0.00071 0.00071 0.00061 0.00059 0.00061 0.00059 0.00059 0.00002 0.00002 0.00002 0.00002 0.00002 0.00002 0.00002 0.00002 0.00002 0.00002 0.00002 0.00002 0.00002 0.00002 0.00002 0.00002 0.00002 0.00002 0.00002 0.00002 0.00002 0.00002 0.00002 0.00002 0.00002 0.00002 0.00002 0.00002 0.00002 0.00002 Transm Distr PPP ND CTC RS TRAC
UDC Total
0.01312 0.01091 0.01034 0.00838 0.00844 0.01046 0.00920 0.00884 0.00769 0.00773 0.00970 0.00868 0.00841 0.00752 0.00755 0.01209 0.01022 0.00976 0.00810 0.00815 0.01046 0.00920 0.00884 0.00769 0.00773 0.00970 0.00868 0.00841 0.00753 0.00755
I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I
Notes: Transmission Energy charges include the Transmission Revenue Balancing Account Adjustment (TRBAA) of $(0.00013) per kWh and the Transmission Access Charge Balancing Account Adjustment (TACBAA) of $0.00031 per kWh. PPP rate is composed of: Low Income PPP rate (LI-PPP) $0.00341 /kWh, Non-low Income PPP rate (Non-LI-PPP) $0.00118 /kWh (pursuant to PU Code Section 399.8, the Non-LI-PPP rate may not exceed January 1, 2000 levels), and Procurement Energy Efficiency Surcharge Rate of $0.00155 /kWh.
3C6
(Continued) Issued by
Date Filed Effective Resolution No.
Mar 11, 2011 Apr 1, 2011
Advice Ltr. No. Decision No.
2237-E
Lee Schavrien
Senior Vice President Regulatory Affairs
Revised
San Diego Gas & Electric Company San Diego, California
Cal. P.U.C. Sheet No. Cal. P.U.C. Sheet No.
20507-E 20261-E Sheet 4
Canceling
Revised
SCHEDULE AL-TOU
GENERAL SERVICE - TIME METERED RATES (Continued)
Rate Components The Utility Distribution Company Total Rates (UDC Total) shown above are comprised of the following components (if applicable): (1) Transmission (Trans) Charges, (2) Distribution (Distr) Charges, (3) Public Purpose Program (PPP) Charges, (4) Nuclear Decommissioning (ND) Charge, (5) Ongoing Competition Transition Charges (CTC), (6) Reliability Services (RS), and (7) Total Rate Adjustment Component (TRAC). Utility Distribution Company (UDC) Total Rate shown above excludes any applicable commodity charges associated with Schedule EECC (Electric Energy Commodity Cost) and Schedule DWR-BC (Department of Water Resources Bond Charge). Certain Direct Access customers are exempt from the TRAC, as defined in Rule 1 – Definitions. Time Periods All time periods listed are applicable to local time. The definition of time will be based upon the date service is rendered. Summer May 1 - Sept 30 Winter All Other On-Peak 11 a.m. - 6 p.m. Weekdays 5 p.m. - 8 p.m. Weekdays Semi-Peak 6 a.m. - 11 a.m. Weekdays 6 a.m. - 5 p.m. Weekdays 6 p.m. - 10 p.m. Weekdays 8 p.m. - 10 p.m. Weekdays Off-Peak 10 p.m. - 6 a.m. Weekdays 10 p.m. - 6 a.m. Weekdays Plus Weekends & Holidays Plus Weekends & Holidays The time periods shown above will begin and end one hour later for the period between the second Sunday in March and the first Sunday in April, and for the period between the last Sunday in October and the first Sunday in November. Non-Standard Seasonal Changeover Customers may select on an optional basis to start the summer billing period on the first Monday of May and to start the winter billing period on the first Monday of October. Customers electing this option will be charged an additional $100 per year for metering equipment and programming. Franchise Fee Differential A Franchise Fee Differential of 5.78% will be applied to the monthly billings calculated under this schedule for all customers within the corporate limits of the City of San Diego. Such Franchise Fee Differential shall be so indicated and added as a separate item to bills rendered to such customers.
T
T
4C13
(Continued) Issued by
Date Filed Effective Resolution No.
Mar 28, 2008 May 1, 2008
Advice Ltr. No. Decision No.
1978-E
08-02-034
Lee Schavrien
Senior Vice President Regulatory Affairs
Revised
San Diego Gas & Electric Company San Diego, California
Cal. P.U.C. Sheet No. Cal. P.U.C. Sheet No.
20508-E 19889-E Sheet 5
Canceling
Revised
SCHEDULE AL-TOU
GENERAL SERVICE - TIME METERED
SPECIAL CONDITIONS 1. 2. 3. 4. Definitions: The Definitions of terms used in this schedule are found either herein or in Rule 1. Voltage: Service under this schedule normally will be supplied at a standard available Voltage in accordance with Rule 2. Voltage Regulators: Voltage Regulators, if required by the customer, shall be furnished, installed, owned, and maintained by the customer. Reconnection Charge: Any customer resuming service within twelve months after such service was discontinued will be required to pay all charges which would have been billed if service had not been discontinued. Non-Coincident Demand Charge: The Non-Coincident Demand Charge shall be based on the higher of the Maximum Monthly Demand or 50% of the Maximum Annual Demand. On-Peak Period Demand Charge: The On-Peak Period Demand Charge shall be based on the Maximum On-Peak Period Demand. Power Factor: The Power Factor rate shall apply to those customers that have a Power Factor Test Failure and will be based on the Maximum Kilovar billing demand. Those customers that have a Power Factor Test Failure will be required to pay for the Power Factor Metering that the utility will install. Parallel Generation Limitation. This schedule is not applicable to standby, auxiliary service or service operated in parallel with a customer's generating plant, except as specified in Rule 1 under the definition of Parallel Generation Limitation. Seasonal Changeover Switching Limitation. Customers who elect the nonstandard Seasonal Changeover option of this schedule will be prohibited from switching service to the regular seasonal changeover for a 12-month period. Limitation on Non-Standard Seasonal Changeover Availability. At the utility's sole option, the optional non-standard seasonal changeover provision is available to no more than ten additional Schedule AL-TOU and Schedule A6-TOU customers annually and; service will be provided in the order in which requests are received. T T T
5. 6. 7.
8.
9.
10.
5C11
(Continued) Issued by
Date Filed Effective Resolution No.
Mar 28, 2008 May 1, 2008
Advice Ltr. No. Decision No.
1978-E
08-02-034
Lee Schavrien
Senior Vice President Regulatory Affairs
Revised
San Diego Gas & Electric Company San Diego, California
Cal. P.U.C. Sheet No. Cal. P.U.C. Sheet No.
21434-E 19718-E Sheet 6
Canceling
Revised
SCHEDULE AL-TOU
GENERAL SERVICE - TIME METERED SPECIAL CONDITIONS (Continued) 11.
Terms of Optional Service. A customer receiving service under this schedule may elect to change to another applicable rate schedule, but only after receiving service on this schedule for at least 12 consecutive months. If a customer elects to discontinue service on this schedule, the customer will not be permitted to return to this schedule for a period of one year. Basic Service Fee Determination. The basic service fee will be determined each month based on the customer’s Maximum Annual Demand. Transmission Multiple Bus Basic Service Fee. This fee shall apply where a customer has at their option elected to be billed at this rate and is limited to where the customer is delivering power and taking service at one or more than one transmission service level bus even if at two or more different voltage levels, for service to a generation facility that is located on a single premise owned or operated by the customer. In such a case, the Utility shall, for the purposes of applying retail rates, combine by subtracting any generation delivered from any loads served provided, however, that for purposes of applying retail rates the difference resulting from this combining may not be less than zero. All other charges on this tariff shall also apply to the resulting combined loads. Any customer selecting this optional billing no later than six (6) months from the first effective date of this new rate shall, for billing purposes, have any previously incurred demand ratchet treated as a “zero” from the effective date of the change in billing forward. In addition, any standby charges shall be adjusted to the customer’s contract level from the effective date of the change in billing forward until the customer’s demand triggers a future change.
12. 13.
14.
Billing. A customer’s bill is first calculated according to the total rates and conditions listed above. The following adjustments are made depending on the option applicable to the customer: a. UDC Bundled Service Customers receive supply and delivery services solely from the Utility. The customer’s bill is based on the Total Rates set forth above. The EECC component is determined by multiplying the EECC price for this schedule during the last month by the customer’s total usage. b. Direct Access (DA) and Community Choice Aggregation (CCA) Customers purchase energy from a non-utility provider and continue to receive delivery services from the Utility. The bills for a DA and CCA Customer will be calculated as if they were a UDC Bundled Service Customer, then crediting the bill by the amount of the EECC component, as determined for a UDC Bundled Customer, and including the appropriate Cost Responsibility Surcharge (CRS) if applicable. Nothing in this service schedule prohibits a marketer or broker from negotiating with customers the method by which their customer will pay the CTC charge.
D
15.
Temporary Service. When service is turned on for cleaning and/or showing of an unoccupied premise above 20 kW facility, the minimal usage shall be billed under Schedule A, until a new tenant begins service. Should usage exceed 20kW at any time for cleaning and/or showing, the customer shall be billed the rates on this schedule.
6C7
(Continued) Issued by
Date Filed Effective Resolution No.
Oct 8, 2009 Jan 1, 2010
Advice Ltr. No. Decision No.
2115-E
09-09-036
Lee Schavrien
Senior Vice President Regulatory Affairs
Revised
San Diego Gas & Electric Company San Diego, California
Cal. P.U.C. Sheet No. Cal. P.U.C. Sheet No.
21774-E 20509-E Sheet 7
Canceling
Revised
SCHEDULE AL-TOU
GENERAL SERVICE - TIME METERED
SPECIAL CONDITIONS (Continued) 16. Multiple Meters on Single Premise. When a single corporate entity owns a contiguous property, not divided by any public right of way or property owned by another entity, all within the same governmental agency’s jurisdiction, and the Utility has more than one meter serving that property, then, at the customer’s request the Utility will for the additional fees and conditions set forth in this Special Condition bill all of the usage at some, or all, of the meters as though the whole premise were served through a single meter. As of September 21, 2004, for new customers to be eligible for combined billing, all meters must have the same billing components. These components include but are not limited to Large Customer CTC Adjustment, Large Customer Commodity Credit, Direct Access (DA) Cost Responsibility Surcharge, DA Utility Service Credit, DA Energy Charge and DA Franchise Fee Surcharge. Meter data will be combined for the purpose of billing UDC charges, as listed in the Rates Section of this tariff, but meter data is not allowed to be combined for the purpose of off setting any charges on SDG&E’s commodity rate schedules.. The customer must pay for the utility to install and maintain meters to record consumption in 15 minute intervals for all involved meters. The customer must also pay a distance adjustment fee determined by the utility that is based on the distance between each of the meters involved using normal utility position to determine that distance. The rate applied will be the Distance Adjustment Fee from the Rate Section of this tariff multiplied by 0.121. Electric Emergency Load Curtailment Plan: As set forth in CPUC Decision 01-04-006, all transmission level customers except essential use customers, OBMC participants, net suppliers to the electrical grid, or others exempt by the Commission, are to be included in rotating outages in the event of an emergency. A transmission level customer who refuses or fails to drop load shall be added to the next curtailment block so that the customer does not escape curtailment. If the transmission level customer fails to cooperate and drop load at SDG&E’s request, automatic equipment controlled by SDG&E will be installed at the customer’s expense per Electric Rule 2. A transmission level customer who refuses to drop load before installation of the equipment shall be subject to a penalty of $6/kWh for all load requested to be curtailed that is not curtailed. The $6/kWh penalty shall not apply if the customer’s generation suffers a verified, forced outage and during times of scheduled maintenance. The scheduled maintenance must be approved by both the ISO and SDG&E, but approval may not be unreasonably withheld. Other Applicable Tariffs: Rules 21, 23 and Schedule E-Depart apply to customers with generators. Generator Operation: The operation of a non-utility generator unless expressly authorized by tariff is prohibited. T
17.
18. 19.
7C5
Issued by
Date Filed Effective Resolution No.
Apr 19, 2010 May 19, 2010
Advice Ltr. No. Decision No.
2165-E
Lee Schavrien
Senior Vice President Regulatory Affairs
San Diego Gas & Electric Company San Diego, California
Cal. P.U.C. Sheet No. Cal. P.U.C. Sheet No.
20504-E 20258-E Sheet 1
Canceling
Revised
SCHEDULE AL-TOU
GENERAL SERVICE - TIME METERED
APPLICABILITY
Applicable to all metered non-residential customers whose monthly maximum demand equals, exceeds, or is expected to equal or exceed 20 kW. This schedule is not applicable to residential customers, except for those three-phase residential customers taking service on this schedule as of April 12, 2007 who may remain on this schedule while service continues in their name at the same service address. Those three-phase residential customers remaining on this schedule who choose to switch to a residential rate schedule may not return to this schedule. This schedule is optionally available to common use and metered non-residential customers whose Monthly Maximum Demand is less than 20 kW. Any customer whose Maximum Monthly Demand has fallen below 20 kW for three consecutive months may, at their option, elect to continue service under this schedule or be served under any other applicable schedule. This schedule is the utility's standard tariff for commercial and industrial customers with a Monthly Maximum Demand equaling or exceeding 20 kW. Non-profit group living facilities taking service under this schedule may be eligible for a 20% California Alternate Rates for Energy (CARE) discount on their bill, if such facilities qualify to receive service under the terms and conditions of Schedule E-CARE. Agricultural Employee Housing Facilities, as defined in Schedule E-CARE, may qualify for a 20% CARE discount on the bill if all eligibility criteria set forth in Form 142-4032 or Form 142-4035 is met. TERRITORY Within the entire territory served by the Utility.
RATES
Description – AL-TOU Transm Basic Service Fees ($/month) 0-500 kW Secondary Primary Secondary Substation Primary Substation Transmission > 500 kW Secondary Primary Secondary Substation Primary Substation Transmission > 12 MW Secondary Substation Primary Substation Trans. Multiple Bus Distance Adjust. Fee Secondary - OH Secondary - UG Primary - OH Primary - UG Distr PPP ND CTC RS TRAC UDC Total
T
$58.22 58.22 16,630.12 16,630.12 84.67 232.87 232.87 16,630.12 16,630.12 338.77 26,185.08 26,185.08 3,000.00 1.23 3.17 1.22 3.13
I I I I I I I I I I I I
$58.22 58.22 16,630.12 16,630.12 84.67 232.87 232.87 16,630.12 16,630.12 338.77 26,185.08 26,185.08 3,000.00 1.23 3.17 1.22 3.13
I I I I I I I I I I I I
1C20
(Continued) Issued by
Date Filed Effective Resolution No.
Mar 28, 2008 May 1, 2008
Advice Ltr. No. Decision No.
1978-E
08-02-034
Lee Schavrien
Senior Vice President Regulatory Affairs
Revised
San Diego Gas & Electric Company San Diego, California
Cal. P.U.C. Sheet No. Cal. P.U.C. Sheet No.
22271-E 22167-E Sheet 2
Canceling
Revised
SCHEDULE AL-TOU
GENERAL SERVICE - TIME METERED
RATES (Continued)
Description – AL-TOU Demand Charges ($/kW) Non-Coincident Secondary Primary Secondary Substation Primary Substation Transmission Maximum On-Peak Summer Secondary Primary Secondary Substation Primary Substation Transmission Winter Secondary Primary Secondary Substation Primary Substation Transmission Power Factor ($/kvar) Secondary Primary Secondary Substation Primary Substation Transmission Transm Distr PPP ND CTC RS TRAC UDC Total
4.88 4.71 4.88 4.71 4.66
R R R R R
8.81 8.67
0.34 0.33 0.34 0.33 0.33
14.03 13.71 5.22 5.04 4.99
R R R R R
1.05 1.01 1.05 1.01 1.00 0.23 0.22 0.23 0.22 0.22
R R R R R R R R R R
5.76 6.51 1.34 0.33 0.25 4.91 5.04 0.20 0.06 0.05
0.54 0.51 0.54 0.25 0.25 0.08 0.08 0.08 0.05 0.05
7.35 8.03 2.93 1.59 1.50 5.22 5.34 0.51 0.33 0.32
R R R R R R R R R R
0.25 0.25 0.25 0.25
0.25 0.25 0.25 0.25
.
2C7
(Continued) Issued by
Date Filed Effective Resolution No.
Mar 11, 2011 Apr 1, 2011
Advice Ltr. No. Decision No.
2237-E
Lee Schavrien
Senior Vice President Regulatory Affairs
Revised
San Diego Gas & Electric Company San Diego, California
Cal. P.U.C. Sheet No. Cal. P.U.C. Sheet No.
22272-E 22168-E Sheet 3
Canceling
Revised
SCHEDULE AL-TOU
GENERAL SERVICE - TIME METERED RATES (Continued)
Description – AL-TOU Energy Charges ($/kWh) On-Peak - Summer Secondary Primary Secondary Substation Primary Substation Transmission Semi-Peak – Summer Secondary Primary Secondary Substation Primary Substation Transmission Off-Peak – Summer Secondary Primary Secondary Substation Primary Substation Transmission On-Peak – Winter Secondary Primary Secondary Substation Primary Substation Transmission Semi-Peak – Winter Secondary Primary Secondary Substation Primary Substation Transmission Off-Peak - Winter Secondary Primary Secondary Substation Primary Substation Transmission 0.00018 0.00018 0.00018 0.00018 0.00018 0.00018 0.00018 0.00018 0.00018 0.00018 0.00018 0.00018 0.00018 0.00018 0.00018 0.00018 0.00018 0.00018 0.00018 0.00018 0.00018 0.00018 0.00018 0.00018 0.00018 0.00018 0.00018 0.00018 0.00018 0.00018 I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I 0.00508 0.00290 0.00230 0.00041 0.00047 0.00296 0.00170 0.00134 0.00024 0.00028 0.00235 0.00135 0.00106 0.00019 0.00022 0.00425 0.00241 0.00192 0.00034 0.00039 0.00296 0.00170 0.00134 0.00024 0.00028 0.00235 0.00135 0.00106 0.00020 0.00022 0.00614 0.00614 0.00614 0.00614 0.00614 0.00614 0.00614 0.00614 0.00614 0.00614 0.00614 0.00614 0.00614 0.00614 0.00614 0.00614 0.00614 0.00614 0.00614 0.00614 0.00614 0.00614 0.00614 0.00614 0.00614 0.00614 0.00614 0.00614 0.00614 0.00614 0.00040 0.00040 0.00040 0.00040 0.00040 0.00040 0.00040 0.00040 0.00040 0.00040 0.00040 0.00040 0.00040 0.00040 0.00040 0.00040 0.00040 0.00040 0.00040 0.00040 0.00040 0.00040 0.00040 0.00040 0.00040 0.00040 0.00040 0.00040 0.00040 0.00040 0.00130 0.00127 0.00130 0.00123 0.00123 0.00076 0.00076 0.00076 0.00071 0.00071 0.00061 0.00059 0.00061 0.00059 0.00059 0.00110 0.00107 0.00110 0.00102 0.00102 0.00076 0.00076 0.00076 0.00071 0.00071 0.00061 0.00059 0.00061 0.00059 0.00059 0.00002 0.00002 0.00002 0.00002 0.00002 0.00002 0.00002 0.00002 0.00002 0.00002 0.00002 0.00002 0.00002 0.00002 0.00002 0.00002 0.00002 0.00002 0.00002 0.00002 0.00002 0.00002 0.00002 0.00002 0.00002 0.00002 0.00002 0.00002 0.00002 0.00002 Transm Distr PPP ND CTC RS TRAC
UDC Total
0.01312 0.01091 0.01034 0.00838 0.00844 0.01046 0.00920 0.00884 0.00769 0.00773 0.00970 0.00868 0.00841 0.00752 0.00755 0.01209 0.01022 0.00976 0.00810 0.00815 0.01046 0.00920 0.00884 0.00769 0.00773 0.00970 0.00868 0.00841 0.00753 0.00755
I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I
Notes: Transmission Energy charges include the Transmission Revenue Balancing Account Adjustment (TRBAA) of $(0.00013) per kWh and the Transmission Access Charge Balancing Account Adjustment (TACBAA) of $0.00031 per kWh. PPP rate is composed of: Low Income PPP rate (LI-PPP) $0.00341 /kWh, Non-low Income PPP rate (Non-LI-PPP) $0.00118 /kWh (pursuant to PU Code Section 399.8, the Non-LI-PPP rate may not exceed January 1, 2000 levels), and Procurement Energy Efficiency Surcharge Rate of $0.00155 /kWh.
3C6
(Continued) Issued by
Date Filed Effective Resolution No.
Mar 11, 2011 Apr 1, 2011
Advice Ltr. No. Decision No.
2237-E
Lee Schavrien
Senior Vice President Regulatory Affairs
Revised
San Diego Gas & Electric Company San Diego, California
Cal. P.U.C. Sheet No. Cal. P.U.C. Sheet No.
20507-E 20261-E Sheet 4
Canceling
Revised
SCHEDULE AL-TOU
GENERAL SERVICE - TIME METERED RATES (Continued)
Rate Components The Utility Distribution Company Total Rates (UDC Total) shown above are comprised of the following components (if applicable): (1) Transmission (Trans) Charges, (2) Distribution (Distr) Charges, (3) Public Purpose Program (PPP) Charges, (4) Nuclear Decommissioning (ND) Charge, (5) Ongoing Competition Transition Charges (CTC), (6) Reliability Services (RS), and (7) Total Rate Adjustment Component (TRAC). Utility Distribution Company (UDC) Total Rate shown above excludes any applicable commodity charges associated with Schedule EECC (Electric Energy Commodity Cost) and Schedule DWR-BC (Department of Water Resources Bond Charge). Certain Direct Access customers are exempt from the TRAC, as defined in Rule 1 – Definitions. Time Periods All time periods listed are applicable to local time. The definition of time will be based upon the date service is rendered. Summer May 1 - Sept 30 Winter All Other On-Peak 11 a.m. - 6 p.m. Weekdays 5 p.m. - 8 p.m. Weekdays Semi-Peak 6 a.m. - 11 a.m. Weekdays 6 a.m. - 5 p.m. Weekdays 6 p.m. - 10 p.m. Weekdays 8 p.m. - 10 p.m. Weekdays Off-Peak 10 p.m. - 6 a.m. Weekdays 10 p.m. - 6 a.m. Weekdays Plus Weekends & Holidays Plus Weekends & Holidays The time periods shown above will begin and end one hour later for the period between the second Sunday in March and the first Sunday in April, and for the period between the last Sunday in October and the first Sunday in November. Non-Standard Seasonal Changeover Customers may select on an optional basis to start the summer billing period on the first Monday of May and to start the winter billing period on the first Monday of October. Customers electing this option will be charged an additional $100 per year for metering equipment and programming. Franchise Fee Differential A Franchise Fee Differential of 5.78% will be applied to the monthly billings calculated under this schedule for all customers within the corporate limits of the City of San Diego. Such Franchise Fee Differential shall be so indicated and added as a separate item to bills rendered to such customers.
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4C13
(Continued) Issued by
Date Filed Effective Resolution No.
Mar 28, 2008 May 1, 2008
Advice Ltr. No. Decision No.
1978-E
08-02-034
Lee Schavrien
Senior Vice President Regulatory Affairs
Revised
San Diego Gas & Electric Company San Diego, California
Cal. P.U.C. Sheet No. Cal. P.U.C. Sheet No.
20508-E 19889-E Sheet 5
Canceling
Revised
SCHEDULE AL-TOU
GENERAL SERVICE - TIME METERED
SPECIAL CONDITIONS 1. 2. 3. 4. Definitions: The Definitions of terms used in this schedule are found either herein or in Rule 1. Voltage: Service under this schedule normally will be supplied at a standard available Voltage in accordance with Rule 2. Voltage Regulators: Voltage Regulators, if required by the customer, shall be furnished, installed, owned, and maintained by the customer. Reconnection Charge: Any customer resuming service within twelve months after such service was discontinued will be required to pay all charges which would have been billed if service had not been discontinued. Non-Coincident Demand Charge: The Non-Coincident Demand Charge shall be based on the higher of the Maximum Monthly Demand or 50% of the Maximum Annual Demand. On-Peak Period Demand Charge: The On-Peak Period Demand Charge shall be based on the Maximum On-Peak Period Demand. Power Factor: The Power Factor rate shall apply to those customers that have a Power Factor Test Failure and will be based on the Maximum Kilovar billing demand. Those customers that have a Power Factor Test Failure will be required to pay for the Power Factor Metering that the utility will install. Parallel Generation Limitation. This schedule is not applicable to standby, auxiliary service or service operated in parallel with a customer's generating plant, except as specified in Rule 1 under the definition of Parallel Generation Limitation. Seasonal Changeover Switching Limitation. Customers who elect the nonstandard Seasonal Changeover option of this schedule will be prohibited from switching service to the regular seasonal changeover for a 12-month period. Limitation on Non-Standard Seasonal Changeover Availability. At the utility's sole option, the optional non-standard seasonal changeover provision is available to no more than ten additional Schedule AL-TOU and Schedule A6-TOU customers annually and; service will be provided in the order in which requests are received. T T T
5. 6. 7.
8.
9.
10.
5C11
(Continued) Issued by
Date Filed Effective Resolution No.
Mar 28, 2008 May 1, 2008
Advice Ltr. No. Decision No.
1978-E
08-02-034
Lee Schavrien
Senior Vice President Regulatory Affairs
Revised
San Diego Gas & Electric Company San Diego, California
Cal. P.U.C. Sheet No. Cal. P.U.C. Sheet No.
21434-E 19718-E Sheet 6
Canceling
Revised
SCHEDULE AL-TOU
GENERAL SERVICE - TIME METERED SPECIAL CONDITIONS (Continued) 11.
Terms of Optional Service. A customer receiving service under this schedule may elect to change to another applicable rate schedule, but only after receiving service on this schedule for at least 12 consecutive months. If a customer elects to discontinue service on this schedule, the customer will not be permitted to return to this schedule for a period of one year. Basic Service Fee Determination. The basic service fee will be determined each month based on the customer’s Maximum Annual Demand. Transmission Multiple Bus Basic Service Fee. This fee shall apply where a customer has at their option elected to be billed at this rate and is limited to where the customer is delivering power and taking service at one or more than one transmission service level bus even if at two or more different voltage levels, for service to a generation facility that is located on a single premise owned or operated by the customer. In such a case, the Utility shall, for the purposes of applying retail rates, combine by subtracting any generation delivered from any loads served provided, however, that for purposes of applying retail rates the difference resulting from this combining may not be less than zero. All other charges on this tariff shall also apply to the resulting combined loads. Any customer selecting this optional billing no later than six (6) months from the first effective date of this new rate shall, for billing purposes, have any previously incurred demand ratchet treated as a “zero” from the effective date of the change in billing forward. In addition, any standby charges shall be adjusted to the customer’s contract level from the effective date of the change in billing forward until the customer’s demand triggers a future change.
12. 13.
14.
Billing. A customer’s bill is first calculated according to the total rates and conditions listed above. The following adjustments are made depending on the option applicable to the customer: a. UDC Bundled Service Customers receive supply and delivery services solely from the Utility. The customer’s bill is based on the Total Rates set forth above. The EECC component is determined by multiplying the EECC price for this schedule during the last month by the customer’s total usage. b. Direct Access (DA) and Community Choice Aggregation (CCA) Customers purchase energy from a non-utility provider and continue to receive delivery services from the Utility. The bills for a DA and CCA Customer will be calculated as if they were a UDC Bundled Service Customer, then crediting the bill by the amount of the EECC component, as determined for a UDC Bundled Customer, and including the appropriate Cost Responsibility Surcharge (CRS) if applicable. Nothing in this service schedule prohibits a marketer or broker from negotiating with customers the method by which their customer will pay the CTC charge.
D
15.
Temporary Service. When service is turned on for cleaning and/or showing of an unoccupied premise above 20 kW facility, the minimal usage shall be billed under Schedule A, until a new tenant begins service. Should usage exceed 20kW at any time for cleaning and/or showing, the customer shall be billed the rates on this schedule.
6C7
(Continued) Issued by
Date Filed Effective Resolution No.
Oct 8, 2009 Jan 1, 2010
Advice Ltr. No. Decision No.
2115-E
09-09-036
Lee Schavrien
Senior Vice President Regulatory Affairs
Revised
San Diego Gas & Electric Company San Diego, California
Cal. P.U.C. Sheet No. Cal. P.U.C. Sheet No.
21774-E 20509-E Sheet 7
Canceling
Revised
SCHEDULE AL-TOU
GENERAL SERVICE - TIME METERED
SPECIAL CONDITIONS (Continued) 16. Multiple Meters on Single Premise. When a single corporate entity owns a contiguous property, not divided by any public right of way or property owned by another entity, all within the same governmental agency’s jurisdiction, and the Utility has more than one meter serving that property, then, at the customer’s request the Utility will for the additional fees and conditions set forth in this Special Condition bill all of the usage at some, or all, of the meters as though the whole premise were served through a single meter. As of September 21, 2004, for new customers to be eligible for combined billing, all meters must have the same billing components. These components include but are not limited to Large Customer CTC Adjustment, Large Customer Commodity Credit, Direct Access (DA) Cost Responsibility Surcharge, DA Utility Service Credit, DA Energy Charge and DA Franchise Fee Surcharge. Meter data will be combined for the purpose of billing UDC charges, as listed in the Rates Section of this tariff, but meter data is not allowed to be combined for the purpose of off setting any charges on SDG&E’s commodity rate schedules.. The customer must pay for the utility to install and maintain meters to record consumption in 15 minute intervals for all involved meters. The customer must also pay a distance adjustment fee determined by the utility that is based on the distance between each of the meters involved using normal utility position to determine that distance. The rate applied will be the Distance Adjustment Fee from the Rate Section of this tariff multiplied by 0.121. Electric Emergency Load Curtailment Plan: As set forth in CPUC Decision 01-04-006, all transmission level customers except essential use customers, OBMC participants, net suppliers to the electrical grid, or others exempt by the Commission, are to be included in rotating outages in the event of an emergency. A transmission level customer who refuses or fails to drop load shall be added to the next curtailment block so that the customer does not escape curtailment. If the transmission level customer fails to cooperate and drop load at SDG&E’s request, automatic equipment controlled by SDG&E will be installed at the customer’s expense per Electric Rule 2. A transmission level customer who refuses to drop load before installation of the equipment shall be subject to a penalty of $6/kWh for all load requested to be curtailed that is not curtailed. The $6/kWh penalty shall not apply if the customer’s generation suffers a verified, forced outage and during times of scheduled maintenance. The scheduled maintenance must be approved by both the ISO and SDG&E, but approval may not be unreasonably withheld. Other Applicable Tariffs: Rules 21, 23 and Schedule E-Depart apply to customers with generators. Generator Operation: The operation of a non-utility generator unless expressly authorized by tariff is prohibited. T
17.
18. 19.
7C5
Issued by
Date Filed Effective Resolution No.
Apr 19, 2010 May 19, 2010
Advice Ltr. No. Decision No.
2165-E
Lee Schavrien
Senior Vice President Regulatory Affairs
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