20040217Supplemental 1st Resp of IPC to Industrial Cust Part III.pdf

IDAHO POWER COMPANY
CASE NO. IPC-O3-
FIRST PRODUCTION REQUEST
INDUSTRIAL CUSTOMERS OF
IDAHO POWER
TT A CHMENT TO
RESPO NSE TO
REQUEST NO.
COLORADO SPRINGS UTILITIES
City Council Volume No.
Fourth Revised Sheet No. 15
Cancels Third Revised Sheet No. 15
ELECTRIC RATES
TlME-OF-DA Y SERVICE -- 500 KW MINIMUM
A V AILABILITY
E8T
Applicable by contract in the Colorado Springs Utilities' (Utilities) electric service area for customers
whose Maximum Demand equals or exceeds 500 kW in any of the last twelve (12) biBing periods.
Service is not available under this schedule for any customer whose Maximum Demand equals or
exceeds 4 000 kW in any of the last twelve (12) biBing periods.
RATE
The bills are the sum of:
Supply Charge
Standard O tion
On-Peak - Per kWh .......................................................................................
Off-Peak - Per kWh.......................................................................................
$0.0462
0227
The total biB, less the sum of: the bil1ing period Per Day Access and Facilities Charge, the Electric
Cost Adjustment charge, and any Optional Service Charges, divided by the total kWh sales, shall
not exceed $0.08/kWh during the biBing period.
Upon appropriate notice and separate contract, the customer may substitute one of the following
options:
tion A: Monthl Variable O tion -This o tion is closed to future customers
On-Peak - Per kWh ............................................................................ $0.0222 + Futures
Off-Peak - Per kWh............................................................................ . 0.0094 + Futures
The on-peak futures price wil1 change monthly and will be based on the average per kWh
price (hi and low) of the NYMEX PALO VERDE electricity futures on the 15th of each
prior month. In cases when the NYMEX is closed, the futures price shall be the first open
market day following the 15th of the month. The off-peak futures shall be the on-peak
futures price times 47%.
tion B: Fixed Price O tion
The Utilities will periodically establish and offer 12-month fixed price contracts as an option
for all customers served on the E8T rate schedule. . The contracts for this option will be
available for execution the 1 st to 15th of the month prior to the beginning of the 12-month
contract. Actual rates will be posted on the Utilities Internet site during this period and wiB
be distributed to the City Auditor on the posting date. Customers or the City Auditor may
protest the proposed rate by filing a letter of protest stating the grounds upon which the
protestant believes the rate is unjust, umeasonable, insufficient, or unduly
Resolution No.16-
Issue Date: November 12 2002
Approval Date: January 14, 2003
Effective Date: February 1 , 2003
COLORADO SPRINGS UTILITIES
City Council Volume No.
Fifth Revised Sheet No. 16
Cancels Fourth Revised Sheet No. 16
ELECTRI CRATES
TlME-OF-DAY SERVICE -- 500 KW MINIMUM E8T
RATE - Cont'
discriminatory/preferential at any tirne through and including 15 days after the posting
date , or the next business day thereafter if such date falls on a weekend or holiday
based upon protests received, or upon its own discretion, the City Council may
suspend and investigate the proposed rate. If the rate is not suspended, it will
automatically be effective for the guarantee period.
tJOn C: 1(jlowatcher O tion
Super-Peak - Per kWh ......................................................................... $0.1759
Normal-Peak - Per kWh ...................................................................... $0.0384
Off-Peak - Per kWh............................................................................. 0.0227
The customer will be given notice of the declaration by CSU of a Super-Peak period.
This notice shall be provided by email or fax to the customer at least 24 hours pnor to
the commencement of the Super-peak period. The Super-peak periods will not be in
effect for any hours that would normally be an Off-Peak hour, and in a contract year
begInning April I and ending March 31 , the cumulative number of Super-peak hours
will not exceed 100.
tion D: Volunta Economic Curtailment Pro
Customers electing the Standard Option service are eligible to also choose the
Voluntary Economic Curtailment Program, provided however, that the customer must
currently have, or wi11 install at its own expense, the requisite phone line and
cO1IDl1unication equipment necessary to provide CSU with the ability to monitor the
customer s real-tIme participation in the Program. CSU will provide the customer
with at least thirty (30) minutes notice in advance of the start of curtailment period.
After receiving the notice of a voluntary economic curtailment from CSU, and prior
to the beginning ofthe curtailment period, a customer may elect to reduce electric use
by a minimum of250 KW, and notify CSU of its intention to participate in the
voluntary curtailment. At the time CSU provides notice of voluntary curtailment to
the customer CSU will also provide a price quote that will be paid to the customer for
each kWh curtailed. The price quote will be no more than 50% of the estimated
wholesale market price for electricity less the tariffed charge per kWh (including the
ECA adjustment). Curtailed kWh will be calculated by CSU based on the difference
between the customer s load at the time of the economic curtailment request and the
maximum customer load existing during the economic curtailment. Should the
customer fail to reduce its electric use by at least 250 KW after notifying CSU of its
intent to participate in the voluntary curtailment, then this provision ceases to be
effective, and customer s normal tariff rates and provisions will apply. After two
Resolution No.62-
Issue Date: February 3 2003
Approval Date: March 25, 2003
Effective Date: April 1 , 2003
COLORADO SPRINGS UTILITIES
City Council Volume No.
Second Revised Sheet No. l6A
Cancels First Revised Sheet No. l6A
ELECTRIC RATES
TIME-OF-DAY SERVICE -- 500 KW MINIMUM E8T
RATE - Cont'
such failures to comply after providing CSU notice to participate in voluntary
curtailments the customer shall no longer be eligible to participate in the Voluntary
Economic Curtailment Program unless otherwise agreed to by CSU.
Access and Facilities Charges
PER DAY ...................................................................................................
(Includes system improvement charges of $0.1548/day)
Demand Charges
On-Peak Billing Demand, Per kW, Per Day.......................................
Off-Peak Bi11ing Demand, Per kW, Per Day.......................................
Electric Cost Adjustment Charge (ECA)
All kWh ...................................................................................................... Sheet No. 41
$12.0000
2391
1968
Optional Service Charges
Discount for Customer Owned Transfonl1ers - CREDIT
On- and Off-Peak Billing Demand, Per kW, Per Day.........................
The total system served beyond the meter must be owned, operated and
maintamed by the customer for the discount to apply.
Enhanced Power Service Charge
Dedicated Substation Capacity Charge
(Applicable to customers requesting Dedicated Substation Capacity
after July 1 1998.
On- and Off-Peak Billing Demand, Per kW, Per Day..........................
Other enhanced power services as specified in the contract and set forth
in the Rules and Regulations section of this tariff. (For customers who
have signed contracts with Enhanced Power Service provisions prior to
February 3 , 1994, the rate shall be $0.1000 per kW charged on the sum
of On- and Off-Peak Billing Demands, per day.
Totalization Service Charge
As specified in the Totalization Service of this tariff..................... Sheet No. 43
$(0.0118)
$0.033
DETERMINA TI ON OF DEMAND
Maximum Demand: the greatest 15 minute load during any time in the billing period adjusted
upward by 1 % for each 1 % that the power factor of customer is below 95% lagging or leading.
Resolution No.16-
Issue Date: November 12, 2002
Approval Date: January 14 2003
Effective Date: February 1 2003
COLORADO SPRINGS UTILITIES
City Council Volume No.
Second Revised Sheet No. 17
Cancels First Revised Sheet No. 17
ELECTRI C RATES
TIME-OF-DA Y SERVICE -- 500 KW MINIMUM EST
DETERMINA TION OF DEMAND - Cont'
Billing Demand
On- Peak: the greatest 15 minute load during On-Peak hours in the billing period adjusted
upward by 1 % for each 1 % that the power factor of customer is below 95% lagging or leading.
Off-Peak: either a) or b), whichever is greater:
a) the greatest 15 minute load during Off-Peak hours in the billing period adjusted
upward by 1 % for each 1 % that the power factor of customer is below 95% lagging or
1eading, minus the On-Peak Billing Demand. Such demand shall not be less than
zero.
b) 75% of the Maximum Demand during the last twelve (12) billing periods, minus the
On-Peak Billing Demand. Such demand shall not be less than zero.
ON-PEAK AND OFF-PEAK PERIODS
On-Peak Periods:
Winter (October - March): 4:00 P.M. - 10:00 P.
Summer (April - September): 11 :00 A.M. - 6:00 P.
On peak periods are Monday through Friday, excluding the holidays as derIDed below.
Off-Peak Periods:
An other hours plus the fonowing legany observed holidays (the 24 hour calendar day
period): 1) New Year s Day, 2) Memorial Day, 3) Independence Day, 4) Labor Day,
5) Thanksgjving Day, 6) Christmas Day.
SUPPLY OPTION CONVERSION
Customers selecting option A or B must remain on these options for one year. Customers
selecting either Option A or B win be subject to the ECA charges during the initial one-year
contract period; subsequent to this initial contract period, customers served under Options A
or B win not be subject to the ECA. During the initial one-year period, in which a customer
has reselected the Standard Service Option, the ECA win not apply; subsequent to this initial
reselect period, customers will be subject to the ECA.
RULES AND REGULATIONS
Service under this schedule win be in accordance with the provisions of the Electric Service
Rules and Regulations of the Utilities, made a part hereof.
Resolution No.16-
Issue Date: November 12, 2002
Approval Date: January 14 2003
Effective Date: February 1 , 2003
COLORADO SPRINGS UTILITIES
City Council Volume No.
Fourth Revised Sheet No. 18
Cancels Third Revised Sheet No. 18
ELECTRI CRATES
TlME-OF-DAY SERVICE -- 4000 KW MINIMUM E8S
AVAILABILITY
Applicable by contract in the Colorado Springs Utilities' (Utilities) electric service area for
customers whose Maximum Demand equals or exceeds 4 000 kW in any of the last twelve
(12) billing periods.
RATE
The bills are the sum of:
Supply Charge
Standard O tions
On-Peak - Per kWh
.............................................................................
Off-Peak - Per kWh..... .............................
................................. ......... .
0475
0220
The total bill , less the sum of: the billing period Per Day Access and Facilities Charge
the Electric Cost Adjustment Charge, and any Optional Service Charges, divided by the
total kWh sales, shall not exceed $0.08/kWh during the bi11ing period.
Upon appropriate notice, the customer may substitute one of the followmg options:
tion A: Monthl Variable O tion -This o tion is closed to future customers
On-Peak - Per kWh ................................................................... $0.0216 + Futures
Off-Peak - Per kWh.................................................................... 0.0092 + Futures
The on-peak futures price will change monthly and will be based on the average per
kWh price (hi and low) of the NYMEX PALO VERDE electricity futures on the 15th
of each prior month. In cases when the NYMEX is closed, the futures price shall be the
first open market day following the 15th of the month. The off-peak futures shall be the
on-peak futures price times 47%.
tion B: Fixed Price O tIOn
The Utilities will periodically establish and offer l2-month fixed price contracts as an
option for all customers served on the E8S rate schedule. The contracts for this option
will be available for execution the 1 sl to 15th of the month prior to the beginning of the 12-
month contract. Actual rates will be posted on the Utilities Internet site during this period
and wi11 be distributed to the City Auditor on the posting date. Customers or the City
Auditor may protest the proposed rate by filing a letter of protest stating the grounds upon
which the protestant believes the rate is unjust, unreasonable, insufficient, or unduly
Resolution No.16-
Issue Date: November 12, 2002
Approval Date: January 14, 2003
Effective Date: February 1 2003
COLORADO SPRINGS UTILITIES
City Council Volume No.
Fifth Revised Sheet No. 19
Cancels Fourth Revised Sheet No. 19
ELECTRIC RATES
TIME-OF-DA Y SERVICE -- 4000 KW MINIMUM ESS
RATE - Cont'
discrimInatory/preferential at any time through and including 15 days after the posting
date, or the next business day thereafter if such date falls on a weekend or holiday
based upon protests received, or upon its own discretion, the City Council may
suspend and investigate the proposed rate. If the rate is not suspended, it will
automatically be effective for the guarantee period.
tion C: 1(jlowatcher O tion
Super-Peak - Per kWh................................................................... ..... . $0.1760
Normal-Peak - Per kWh ..................................................................... . $0.0373
Off-Peak - Per kWh............................................................................. $0.0220
The customer will be given notice of the declaration by CSU of a Super-Peak period.
This notIce shall be provided by email or fax to the customer at least 24 hours prior to
the commencement of the Super-peak period. The Super-peak periods will not be in
effect for any hours that would nonl1ally be an Off-Peak hour, and in a contract year
beginning April 1 and ending March 31 , the cumulative number of Super-peak hours
will not exceed 100.
tion D: Volunta Economic Curtailment Pro ram
Customers electing the Standard Option service are eligible to also choose the
Voluntary Economic Curtailment Program, provided, however, that the customer
must currently have, or will install at its own expense, the requisite phone line and
communication equipment necessary to provide CSU with the ability to monitor the
customer s real-time participation m the Program. CSU will provide the customer
with at least thirty (30) minutes notice in advance of the start of curtailment period.
After receiving the notice of a voluntary economic curtailment from CSU, and prior
to the beginning of the curtailment period , a customer may elect to reduce electric use
by a minimum of250 KW, and notify CSU of its intention to participate in the
voluntary curtailment. At the time CSU provides notice of voluntary curtailment to
the customer CSU will also provide a price quote that will be paid to the customer for
each kWh curtailed. The price quote will be no more than 50% of the estimated
wholesale market price for electricity less the tariffed charge per kWh (including the
ECA adjustment). Curtailed kWh will be calculated by CSU based on the difference
between the customers ' load at the time of the economic curtailment request and the
maximum customer load existing during the economic curtailment.
Resolution No.62-
Issue Date: February 3 , 2003
Approval Date: March 25 , 2003
Effective Date: April 1 , 2003
COLORADO SPRINGS UTILITIES
City Council Volume No.
First Revised Sheet No. 19A
Cancels Original Sheet No. 19A
ELECTRI C RATES
TIME-OF-DA Y SERVICE -- 4000 KW MINIMUM E8S
RATE - Cont'
Should the customer fail to reduce its electric use by at least 250 KW after notifying
CSU of its intent to participate in the voluntary curtailment, then this provision ceases
to be effective, and customer s nonl1al tariff rates and provisions will apply. After
two such failures to comply after providing CSU notice to participate in voluntary
curtailments the customer shall no longer be eligible to participate in the Voluntary
Economic Curtailment Program unless otherwise agreed to by CSU.
Access and FaciJities Charges
Per Day......... ...... ................................. ...... ........................ .......... ....".......... $20.0000
(Includes system improvement charges of $0.1548/day)
Demand Charges
On-Peak Billing Demand, Per kW, Per Day..............................................
Off-Peak Billing Demand, Per kW, Per Day.............................................
Electric Cost Adjustment Charge (ECA)
All kWh.......................................................................................................Sheet No. 41
2335
1918
Optional Service Charges
Discount for Customer Owned Transformers - CREDIT
On- and Off-Peak Billing Demand, Per kW, Per Day.........................
The total system served beyond the meter wi11 be owned, operated and
maintained by the customer.
Enhanced Power Service Charge
Dedicated Substation Capacity Charge
(Applicable to customers requesting Dedicated SubstatIOn Capacity
after July 1 , 1998.
On- and Off-Peak Billing Demand, Per kW, Per Day..........................
$(0.0118)
$0.033
Other enhanced power services as specified in the contract and set forth
in the Rules and Regulations section ofthis tariff. (For customers who
have signed contracts with Enhanced Power Service provisions pnor to
February 3 , 1994 , the rate shall be $0.1000 per kW charged on the sum
of On- and Off-Peak Billing Demands, per day.
Totalization Service Charge
As specified in the Totalization Service of this tariff.....................Sheet No. 43
Resolution No.64-
Issue Date: March 28 2001
Approval Date: April 10 2001
Effective Date: April 11 2001
COLORADO SPRINGS UTILITIES
City Council Volume No.
Second Revised Sheet No. 20
Cancels First Revised Sheet No. 20
ELECTRI CRATES
TIME-OF-DAY SERVICE -- 4000 KW MINIMUM E8S
DETERMINA TION OF DEMAND
Maximum Demand: the greatest 15 minute load d:uring any time in the billing period adjusted
upward by 1 % for each 1 % that the power factor of customer is below 95% lagging or leading.
Billing Demand
On- Peak: the greatest 15 minute load during On-Peak hours in the billing period adjusted
upward by 1 % for each 1 % that the power factor of customer is below 95% lagging or leading.
Off-Peak: either a) or b), whichever is greater:
a) the greatest 15 minute load during Off-Peak hours in the billing period adjusted upward
by 1 % for each 1 % that the power factor of customer is below 95% lagging or leading,
minus the On-Peak Billing Demand. Such demand shan not be less than zero.
b) 75% of the Maximum Demand during the last twelve (12) billing periods, minus the
On-Peak Bi11ing Demand. Such demand shan not be less than zero.
ON-PEAK AND OFF-PEAK PERIODS
On-Peak Periods:
Winter (October - March): 4:00 P.M. - 10:00 P.
Summer (April - September): 11 :00 A.M. - 6:00 P.
On peak periods are Monday through Friday, excluding the holidays as derIDed below.
Off-Peak Periods:
All other hours plus the fonowing 1egally observed holidays (the 24 hour calendar day
period): 1) New Year s Day, 2) Memorial Day, 3) Independence Day, 4) Labor Day,
5) Thanksgiving Day, 6) Christmas Day.
SUPPLY OPTION CONVERSION
Customers selecting option A or B must remain on these optJOns for one year. Customers
selecting either OptIon A or B will be subject to the ECA charges during the initial one-year
contract period; subsequent to this initial contract period, customers served under Options A
or B will not be subject to the ECA. During the initial one-year period, in which a customer
has reselected the Standard Service Option, the ECA wi11 not apply; subsequent to this initial
reselect period, customers will be subject to the ECA.
RULES AND REGULATIONS
Service under this schedule will be in accordance with the provisions of the Electric Service
Rules and Regulations of the Utilities, made a part hereof.
Resolution No.16-
Issue Date: November 12 , 2002
Approval Date: January 14 2003
Effective Date: February 1 , 2003
roT so'
Southern California Edison
Rosemead, California
Revised
Cancelling Revised
Cal. PUC Sheet No. 30935-
Cal. PUC Sheet No. 29038-
~ 'DOO" ,"W""'D"AL Com,..,
Schedule TOU-
TIME-OF-USE - GENERAL SERVICE - LARGE
Sheet 1
APPLICABILITY
Applicable to general service including lighting and power, except agricultural water pumping accounts
as described in Special Condition 12. This Schedule is applicable to and mandatory for all customers (T)
whose monthly maximum demand, in the opinion of SCE, is expected to exceed 500 kW or has
exceeded 500 kW in any three months during the preceding 12 months, except that customers served
on this Schedule may elect service under any applicable schedules optional hereto. Except for
interruptible service customers, any existing customer on this Schedule whose monthly maximum
demand has registered 500 kW or less for 12 consecutive months is ineligible for service under this
Schedule (See Special Condition No. 11). Service under this Schedule is subject to meter availability.
TERRITORY
Within the entire territory served.
RATES
The following rates are set forth for service metered and delivered at secondary, primary, and
subtransmission voltages.
SERVICE METERED AND DELIVERED AT VOLTAGES BELOW 2 kV
Per Meter Per Month
Summer Winter
Customer Charge........................................................................... $298.$298.
Demand Charge (to be added to Customer Charge):
Facilities Related Component:
All kW of Billing Demand, except that the Billing
Demand shall not be less than the levels set forth
in Special Condition No.4 below
per kW ................................................................. $6.40 6.40
Time Related Component (to be added to Facilities
Related Component):
All kW of On-Peak Billing Demand, per kW ....... ............. $ 17.
Plus all kW of Mid-Peak Billing Demand, per kW............. $ 2.
Plus all kW of Off-Peak Billing Demand, per kW.............. $ 0.
N/A$ 0.$ 0.
(Continued)
(To be inserted by utility)
Advice 1607-
Decision
Issued by
John R. Fielder
Senior Vice President
(To be inserted by Cal. PUC)
Date Filed Apr 2, 2002
Effective Apr 1 , 2002
Resolution E-37651C13
E"i5'i soA
~ ,."."
'""""AT""'" ~m,'"
Southern California Edison
Rosemead , California
Revised
Cancelling Revised
Cal. PUC Sheet No. 29258-
Cal. PUC Sheet No. 29039-
Schedule TOU-
TIME-OF-USE - GENERAL SERVICE - LARGE
Sheet 2
(Continued)
RATES (Continued)
SERVICE METERED AND DELIVERED AT VOLTAGES BELOW 2 kV (Continued)
Per Meter Per Month
Summer Winter
Energy Charge (to be added to Demand Charge):
All On-Peak kWh, per kWh............................................................ $0.20206
Plus all Mid-Peak kWh , per kWh ................................................... $0.11039
Plus all Off-Peak kWh , per kWh .................................................... $0.08860
N/A
$0.12386
$0.08975
During Summer months a Peak Period Rate Limiter of $1.20251 per kilowatthour and Average Rate
Limiter of $0.37205 per kilowatthour will apply (See Special Condition Nos. 12 and 13).
The above charges used for customer billing are determined using the components shown in
the Rate Components Section following the Special Conditions Section.
SERVICE METERED AND DELIVERED AT VOLTAGES FROM 2 kV THROUGH 50 KV
Per Meter Per Month
Summer Winter
Customer Charge ............................................................................. $299.$299.
Demand Charge (to be added to Customer Charge):
Facilities Related Component:
All kW of Billing Demand , except that the Billing
Demand shall not be less than the levels set forth
in the Special Condition No.4 below
per kW .............................................................................$ 6.$ 6.
Time Related Component (to be added to Facilities
Related Component):
All kW of On-Peak Billing Demand, per kW ..................."
Plus all kW of Mid-Peak Billing Demand, per kW.............
Plus all kW of Off-Peak Billing Demand, per kW..............
$ 17.$ 2.$ 0.
N/A
$ 0.$ 0.
(Continued)
(To be inserted by utility)
Advice 1545-
Decision 01-05-064
Issued by
John R. Fielder
Senior Vice President
(To be inserted by Cal. PUC)
Date Filed May 22, 2001
Effective Jun 3, 2001
Resolution2C12
roT SOA
'MON '~"NAnON,u. c.~,.",Revised
Cancelling Revised
Cal. PUC Sheet No. 31766-
Cal. PUC Sheet No. 29259-Southern California Edison
Rosemead, California
Schedule TOU-
TIME-OF-USE - GENERAL SERVICE - LARGE
(Continued)
RATES (Continued)
Sheet 3
SERVICE METERED AND DELIVERED AT VOLTAGES FROM 2 kV THROUGH 50 KV (Continued)
Per Meter Per Month
Summer Winter
Energy Charge (to be added to Demand Charge):
All On-Peak kWh, per kWh ........................................................... $0.19544
Plus all Mid-Peak kWh, per kWh .................................................. $0.10897
Plus all Off-Peak kWh, per kWh ................................................... $0.08808
N/A
$0.12121
$0.08924
During Summer months a Peak Period Rate Limiter of $1.19437 per kilowatthour and Average Rate Limiter
of $0.36938 per kilowatthour will apply (See Special Condition Nos. 12 and 13),
The above charges used for customer billing are determined using the components shown in
the Rate Components Section following the Special Conditions Section.
SERVICE METERED AND DELIVERED AT VOLTAGES ABOVE 50 KV
Per Meter Per Month
Summer Winter
Customer Charge ............................................................................. $349.45
Demand Charge (to be added to Customer Charge):
Facilities Related Component:
All kW of Billing Demand, except that the Billing
Demand shall not be less than the levels set forth in
Special Condition No.4 below, per kW .. .............."......... $
Time Related Component (to be added to Facilities
Related Component):
All kW of On-Peak Billing Demand, per kW ............"...... $ 13.40
Plus all kW of Mid-Peak Billing Demand, per kW............. $ 2.
Plus all kW of Off-Peak Billing Demand, per kW ............. $ 0.
(Continued)
$349.45
(I)
N/A$ 0.$ 0.
(R)
(R)
(To be inserted by utility)
Advice 1641-
Decision
Issued by
John R. Fielder
Senior Vice President
3C5
(To be inserted by Cal. PUG)
Date Filed Jan 21 , 2003
Effective Sep 1 , 2002
Resolution
E"oT sON
'DDDN ,""'~mDNAL Cc~...,
Southern California Edison
Rosemead, California
Revised
Cancelling Revised
Cal. PUC Sheet No. 29260-
Cal. PUC Sheet No. 29041-
Schedule TOU-
TIME-OF-USE - GENERAL SERVICE - LARGE
Sheet 4
(Continued)
RATES (Continued)
SERVICE METERED AND DELIVERED AT VOLTAGES ABOVE 50 KV (Continued)
Per Meter Per Month
Summer Winter
Energy Charge (to be added to Demand Charge):
All On-Peak kWh, per kWh ........................................................... $0.18292
Plus all Mid-Peak kWh, per kWh .................................................. $0.09963
Plus all Off-Peak kWh, per kWh ................................................... $0.08665
N/A
$0.11003
$0.08782
During Summer months a Peak Period Rate Limiter of $1.03145 per kilowatthour will apply (See Special
Condition No. 12).
The above charges used for customer billing are determined using the components shown in
the Rate Components Section following the Special Conditions Section.
SPECIAL CONDITIONS
Time periods are defined as follows:
On-Peak: Noon to 6:00 p.m. summer weekdays except holidays
Mid-Peak: 8:00 a.m. to Noon and 6:00 p.m. to 11 :00 p.m. summer
weekdays except holidays
8:00 a.m. to 9:00 p.m. winter weekdays except holidays
All other hours.Off-Peak:
Holidays are New Year s Day (January 1), Washington s Birthday (third Monday in
February), Memorial Day (last Monday in May), Independence Day (July 4), Labor Day
(first Monday in September), Veterans Day (November 11), Thanksgiving Day (fourth
Thursday in November), and Christmas (December 25).
See Special Condition No. 15 for Time Periods applicable to Qualifying Facilities.
When any holiday listed above falls on Sunday, the following Monday will be recognized as an
off-peak period. No change will be made for holidays falling on Saturday.
The summer season shall commence at 12:00 a.m. on the first Sunday in June and continue
until 12:00 a.m. of the first Sunday in October of each year. The winter season shall
commence at 12:00 a.m. on the first Sunday in October and continue until 12:00 a.m. of the
first Sunday in June of the following year.
(Continued)
(To be inserted by utility)
Advice 1545-
Decision 01-05-064
Issued by
John R. Fielder
Senior Vice President
(To be inserted by Cal. PUe)
Date Filed May 22, 2001
Effective Jun 3, 2001
Resolution4C11
EJ roT sON
,""ON 'NT..NmONAL eo..,.,Revised
Revised
Cal. PUC Sheet No. 29042-
Cal. PUC Sheet No. 27065-Southern California Edison
Rosemead, California Cancelling
Sheet 5Schedule TOU-
TIME-OF-USE - GENERAL SERVICE - LARGE
(Continued)
SPECIAL CONDITIONS (Continued)
Voltage: Service will be supplied at one standard voltage.
Maximum Demand: Maximum demands shall be established for the On-Peak, Mid-Peak , and
Off-Peak periods. The maximum demand for each period shall be the measured maximum
average kilowatt input indicated or recorded by instruments to be supplied by SCE, during any
15-minute metered interval, but, where applicable, not less than the diversified resistance welder
load computed in accordance with the section designated Welder Service in Rule No.2. Where
the demand is intermittent or subject to violent fluctuations, a 5-minute interval may be used.
Billing Demand: The Billing Demand shall be the kilowatts of Maximum Demand, determined to
the nearest kW. The Demand Charge shall include the following billing components. The Time
Related Component shall be for the kilowatts of Maximum Demand recorded during (or
established for) the monthly billing period for each of the On-Peak, Mid-Peak , and Off-Peak Time
Periods. The Facilities Related Component shall be for the greater of the kilowatts of Maximum
Demand recorded during (or established for) the monthly billing period or 50% of the highest
Maximum Demand established in the preceding eleven months (Ratcheted Demand). However
when SCE determines the customer s meter will record little or no energy use for extended
periods of time or when the customers meter has not recorded a Maximum Demand in the
preceding eleven months, the Facilities Related Component of the Demand Charge may be
established at 50 percent of the customer s connected load. Separate Demand Charge(s) for the
On-Peak, Mid-Peak, and Off-Peak Time Periods shall be established for each monthly billing
period. The Demand Charge for each time period shall be based on the Maximum Demand for
that time period occurring during the respective monthly billing period.
Excess Transformer Capacity: Excess Transformer Capacity is the amount of transformer
capacity requested by a customer, or required by SCE, in excess of that which SCE would
normally install to serve the customer s Maximum Demand. Excess Transformer Capacity shall
be billed at $1.00 per kVA per month.
(Continued)
(To be inserted by utility)
Advice 1530-
Decision 01-04-006
Issued by
John R. Fielder
Senior Vice President
(To be inserted by Cal. PUC)
Date Filed Apr 13. 2001
Effective Apr 14 , 2001
Resolution5C7
~ E'"6"1s0"
Southern California Edison
Rosemead , California
Revised
Cancelling Revised
Cal. PUC Sheet No. 29043-
Cal. PUC Sheet No. 27066-
~ ,",,".
"","."'"NAL c..".,
Schedule TOU-
TIME-OF-USE - GENERAL SERVICE - LARGE
Sheet 6
(Continued)
SPECIAL CONDITIONS (Continued)
Power Factor Adjustment:
Adjustment Rate:
(1 )For service delivered and metered at voltages greater than 50 kV, including
Cogeneration and Small Power Production Customers, the billing will be
increased by $0.18 per kilovar of maximum reactive demand imposed on SCE.
(2)For service delivered and metered at voltages of 50 kV or less, including
Cogeneration and Small Power Production Customers, the billing will be
increased by $0.23 per kilovar of maximum reactive demand imposed on SCE.
Determining the Reactive Demand:
The maximum reactive demand shall be the highest measured maximum average
kilovar demand indicated or recorded by metering to be supplied by SCE during any
15 minute metered interval in the month. The kilovars shall be determined to the
nearest unit. A device will be installed on each kilovar meter to prevent reverse
operation of the meter.
Temporary Discontinuance of Service: Where the use of energy is seasonal or intermittent, no
adjustments will be made for a temporary discontinuance of service. Any customer prior to
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.
(Continued)
(To be inserted by utility)
Advice 1530-
Decision 01-04-006
Issued by
John R. Fielder
Senior Vice President
(To be inserted by Cal. PUG)
Date Filed Apr 13, 2001
Effective Apr 14, 2001
Resolution6C7
toT SOA
,.. '""00 ,~"O"'ON~ Com,..,
Southern California Edison
Rosemead , California Cancelling
Revised
Revised
Cal. PUC Sheet No. 29044-
Cal. PUC Sheet No. 27067-
Schedule TOU-
TIME-OF-USE - GENERAL SERVICE - LARGE
Sheet 7
(Continued)
SPECIAL CONDITIONS (Continued)
Supplemental Visual Demand Meter: Subject to availability, and upon written application by
the customer, SCE will , within 180 days, supply and install a SCE-owned supplemental visual
demand meter. The customer shall provide the required space and associated wiring beyond
the point of interconnection for such installation. Said supplemental visual demand meter shall
be in parallel with the standard billing meter delineated in Special Condition 3 above. The
readings measured or recorded by the supplemental visual demand meter are for customer
information purposes only and shall not be used for billing purposes in lieu of meter readings
established by the standard billing meter. If a meter having visual capability of displaying real
time demand is installed by SCE as the standard billing meter, no additional metering will be
installed pursuant to this Special Condition.
One of the following types of supplemental visual demand meters will be provided in
accordance with provisions above at no additional cost to the customer: Dial Wattmeter or
Electronic Demand Monitor.
If the customer desires a supplemental visual demand meter having features not available in
any of the above listed meters, such as an electronic microprocessor-based meter, SCE will
provide such a supplemental visual demand meter subject to a monthly charge, if the meter
and its associated equipment have been approved for use by SCE. Upon receipt from the
customer of a written application SCE will design the installation and will thereafter supply,
install , and maintain the supplemental visual demand meter subject to all conditions stated in
the first and last paragraph of this Special Condition. For purposes of computing the monthly
charge, any such supplemental visual demand meter and associated equipment shall be
treated as Added Facilities in accordance with Rule No.2, Paragraph H , Section 1 and 2 of the
tariff rules. Added investment for computing the monthly charge shall be reduced by SCE'
estimated total installed cost at the customer location of the Electronic Demand Monitor
offered otherwise herein at no additional cost.
SCE shall have sole access for purposes of maintenance and repair to any supplemental
visual demand meter installed pursuant to this Special Condition and shall provide all required
maintenance and repair. Periodic routine maintenance shall be provided at no additional cost
to the customer. Such routine maintenance includes making periodic adjustments, lubricating
moving parts and making minor repairs. Non-routine maintenance and major repairs or
replacement shall be performed on an actual cost basis with the customer reimbursing SCE
for such cost.
Contracts: An initial three-year facilities contract may be required where applicant requires
new or added serving capacity exceeding 2,000 kVA.
(Continued)
(To be inserted by utility)
Advice 1530-
Decision 01-04-006
Issued by
John R. Fielder
Senior Vice President
(To be inserted by Gal. PUG)
Date Filed Apr 13, 2001
Effective Apr 14, 2001
Resolution7C7
E"i5'\ so'
.. 'O"ON mTnNATWN,u,
~~""
Southern California Edison
Rosemead, California
Revised
Revised
Cal. PUC Sheet No.
Cal. PUC Sheet No.
29045-
27068-Cancelling
Sheet 8Schedule TOU-
TIME-OF-USE - GENERAL SERVICE - LARGE
(Continued)
10.
SPECIAL CONDITIONS (Continued)
Customer-Owned Electrical Generating Facilities:
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.
Customer-owned electrical generating facilities used solely for auxiliary, emergency, or
standby purposes (auxiliary/emergency generating facilities) to serve the customer
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 to allow the customer to test the
auxiliary/emergency generating facilities. A Momentary Parallel Generation Contract is
required for this type of service.
11.Removal From Schedule: Customers receiving service under this Schedule whose monthly
Maximum Demand has registered 500 kW or less for 12 consecutive months shall be changed
to an applicable rate schedule effective with the date the customer became ineligible for service
under this Schedule. This Special Condition is not applicable to customers taking service under
Schedule 1-
12.Peak Period Rate Limiter: A firm service customer s total monthly bill under this Schedule,
excluding the Public Utilities Commission (PUe) Reimbursement Fee, California Alternate Rates
for Energy (CARE) Surcharge , as set forth in Preliminary Statement, Part 0 , Section 5, Power
Factor Adjustment, Excess Transformer Capacity charge, Non-Time Related Demand Charge,
and customer charges, shall be reduced, if necessary, so that the average rate during the On-
Peak Period in a summer month does not exceed the peak period rate limiter for the appropriate
service voltage level shown on this Schedule. This Special Condition is also applicable to firm
service customers taking service under Schedule S. This Special Condition is not applicable to
customers taking service under Schedule 1-
13.Average Rate Limiter: For firm service customers with service metered and delivered at voltages
50 kV and below, the customer s total monthly bill under this Schedule, excluding the PUC
Reimbursement Fee CARE Surcharge, as set forth in Preliminary Statement, Part 0
Section 5, Power Factor Adjustment, Excess Transformer Capacity charge, and customer
charges, shall be reduced, if necessary, so that the average rate during a summer month does
not exceed the average rate limiter for the appropriate service voltage level shown on this
Schedule. This Special Condition is not applicable to customers taking service under
Schedule 1-
14.Agricultural Water Pumping Accounts: Large individual water agency and other large water
pumping accounts with 70% or more of the water pumped used for agricultural purposes are not
eligible for service under this Schedule and must take service on an agricultural class rate
schedule.
(Continued)
(To be inserted by utility)
Advice 1530-
Decision 01-04-006
Issued by
John R. Fielder
Senior Vice President
(To be inserted by Cal. PUC)
Date Filed Apr 13, 2001
Effective Apr 14, 2001
ResolutionBC?
~ E"OTSOR
~ ,",,""
,~,..m"'AL Com,..,
Southern California Edison
Rosemead, California
Revised
Cancelling Revised
Cal. PUC Sheet No.
Cal. PUC Sheet No.
29046-
27069-
Schedule TOU-
TIME-OF-USE - GENERAL SERVICE - LARGE
Sheet 9
(Continued)
SPECIAL CONDITIONS (Continued)
15.Qualifying Facilities Time Periods: Time Periods for power purchase payments to a
cogeneration or small power production source which meets the criteria for a Qualifying
Facility as defined under 18 CFR, Chapter 1 , part 292, subpart B of the Federal Energy
Regulatory Commission regulations and whose power purchase payments are based on the
time-of-use periods set forth in this Schedule , shall be as defined under Special Condition
No.1 herein, except that: 1) consistent with the effective dates listed in the table below, the
summer season shall commence at 12:00 a.m. on June 1 and continue until 12:00 a.m. on
October 1 of each year; 2) consistent with the effective dates listed in the table below, the
winter season shall commence at 12:00 a.m. on October 1 of each year and continue until
12:00 a.m. on June 1 of the following year; 3) for the winter season a Super Off-Peak time
period of midnight to 6:00 a., everyday, shall apply.
The Summer and Winter Season modifications defined above shall become effective for each
Qualifying Facility based on its date of Firm Operation (or initial operation for non-firm
Qualifying Facilities) as shown on the table below. Qualifying Facilities that began operation
after the end of the Summer Season will be considered to have begun operation in the next
year.
Firm Operation
Effective
June 1
1985 and prior years
1986
1987
1988
1989
1990
1991
1992 and years beyond
1994
1993
1992
1992
1993
1994
1993
1992
Qualifying Facilities may elect, on a one-time basis , to receive metered kWh hourly deliveries
rather than the above time periods. Those Qualifying Facilities not electing to make this
change shall continue to receive power purchase payments for energy and capacity based on
time-of-use and seasonal periods as defined above.
(Continued)
(To be inserted by utility)
Advice 1530-
Decision 01-04-006
Issued by
John R. Fielder
Senior Vice President
(To be inserted by Cal. PUG)
Date Filed Apr 13, 2001
Effective Apr 14, 2001
Resolution9Cl
roT sON
'D"DN ,NT"NAnDN'" eo.".,
Southern California Edison
Rosemead, California
Revised
Revised
Cal. PUC Sheet No. 29047-
Cal. PUC Sheet No. 27070-Cancelling
Sheet 10Schedule TOU-
TIME-OF-USE - GENERAL SERVICE - LARGE
(Continued)
SPECIAL CONDITIONS (Continued)
16.Compensated Metering. This provision is applicable to service metered and delivered at
voltages above 50 kV. Where customer/applicant requests and SCE agrees, SCE may install
a transformer loss compensating device (Compensated Metering) acceptable to SCE in order
to provide high voltage (over 50 kV) metered service. Where provided, this service will be
considered as metered and delivered on SCE's side of the serving transformer. SCE shall rely
on transformer loss data provided by the transformer manufacturer or transformer loss tests
pertormed by SCE to calibrate the compensating device. Service under this provision is
contingent upon customer/applicant's entering into an agreement which requires payment for
the serving transformer and related substation equipment in accordance with Rule 2.
Section H , Added Facilities, except where such transformer equipment is owned, operated
and maintained by the customer/applicant. Where the transformer equipment is owned
operated , and maintained by the customer/applicant, the customer/applicant is required to pay
for the Compensated Metering and related equipment in accordance with Rule 2., Added
Facilities , and shall also agree to provide SCE unrestricted access to the serving transformer
metering, and compensating equipment.
17.Economic Development Rate Discount: The economic development rate discount is
applicable to new customers who agree to a written non-renewable contract and will locate
new operations (new electric usage) within: Enterprise Zones designated by the State of
California under the Enterprise Zone Act; Economic Incentive Areas designated by the State
under the Employment and Economic Incentive Act; Recycling Market Development Zones
designated by the California Integrated Waste Management Board under the Public Resource
Code relating to solid waste; or federal military bases that are scheduled to be closed. Such
new operations shall have loads that exceed 500 kW of monthly Maximum Demand. New
customers locating on federal military bases scheduled for closure must declare their intention
to continue as a customer of SCE after the base closure. Application will be limited to either a
maximum of 50 qualified participants or a combined net load addition for all participants of 50
megawatts. The discount which is limited to a 3-year period , is 15 percent for the first
month period , 10 percent for the second 12 month period, and 5 percent for the third 12 month
period. It shall be applied to the customer total monthly bill excluding the PUC
Reimbursement Fee, CARE Surcharge, as set forth in Preliminary Statement, Part 0, Section
, and any other applicable taxes and charges as specified in the Contract. For purposes
revenue accounting the discount will be deducted from the distribution component of the total
rate.
(Continued)
(To be inserted by utility)
Advice . 1530-
Decision 01-04-006
Issued by
John R. Fielder
Senior Vice President
(To be inserted by Cal. PUG)
Date Filed Apr 13, 2001
Effective Apr 14, 2001
Resolution10C7
EDT sON
~ 'MO" '"T~"mO"AL c.=,..,
Southern California Edison
Rosemead , California
Revised
Cancelling Revised
Cal. PUC Sheet No.
Cal. PUC Sheet No.
29048-
27071-
Schedule TOU-
TIME-OF-USE - GENERAL SERVICE - LARGE
Sheet 11
(Continued)
SPECIAL CONDITIONS (Continued)
17.Economic Development Rate Discount: (Continued)
New electric usage does not represent kWh and kW that already exists within the State of
California.
The Contract provides for a delay in the commencement of the three-year economic
development rate discount for up to a 24 month period to provide time to establish operations
within Enterprise Zones, Economic Incentive Areas, or federal military bases scheduled for
closure.
This Special Condition is not applicable to governmental entities, to customers taking service
under Schedule S, or existing customers for incremental increases in electric load at existing
operations whether or not such operations are located within Enterprise Zones, Economic
Incentive Areas , Recycling Market Development Zones, or federal military bases scheduled for
closure.
This Special Condition is closed to new customers as of December 31 , 1998 and will expire
December 31 , 2003.
18.Rate Eligibility Criteria for Energy Efficiency (RECEE)
The purpose of the RECEE is to determine a customer s continued eligibility for service under
this Schedule. The RECEE is applicable to customers currently receiving service under this
Schedule and who have implemented energy efficiency measures on or after June 5, 1994 which
have reduced the customer's monthly Maximum Demand to 500 kW or less. The RECEE is a
fixed level of demand , determined by SCE , based on the customer s permanent demand
reduction resulting from the implementation of energy efficiency measures. The RECEE
demand is set forth in the Energy Efficiency Declaration, Form No.16-327.
The RECEE demand plus the customer s actual demand will be evaluated each billing period for
purposes of determining the customer s continued eligibility for service under this Schedule. If
the RECEE demand plus the customer s actual demand equals 500 kW or less for
consecutive months, the customer is ineligible for service under this Schedule and ineligible for
application of the RECEE. The RECEE demand will not be used for purposes of calculating the
customer s demand charge.
(Continued)
(T 0 be inserted by utility)
Advice 1530-
Decision 01-04-006
Issued by
John R. Fielder
Senior Vice President
(To be inserted by Cal. PUC)
Date Filed Apr 13 , 2001
Effective Apr 14, 2001
ResolutionIIC?
~ fo", soo
Southern California Edison
Rosemead, California Cancelling
Revised
Revised
Cal. PUC Sheet No. 31896-
Cal. PUC Sheet No. 30936-
'"'
'0"0" ,"""""'0""'" c.=...,
Schedule TOU-
TIME-OF-USE - GENERAL SERVICE - LARGE
Sheet 12
(Continued)
SPECIAL CONDITIONS (Continued)
19.Voltage Discount: For customers receiving service at 220 kV, the customer s total monthly bill for
charges under this Schedule , excluding the PUC Reimbursement Fee and CARE Surcharge as
set forth in Preliminary Statement, Part 0, Section 5, shall be reduced by 12.4 percent.
20.Optimal Billing Period Service: This experimental special condition provides for the voluntary use
of an Optimal Billing Period (OBP) which allows for a customer s billing cycle(s) to coincide with
the customer s high seasonal production cycle. The customer designates the OBP by selecting
a specific month and day for the start of the OBP and a specific month and day for the end of the
asP. The start and end dates must fall within the customer s high seasonal production cycle. In
no event shall any revised billing period exceed 45 days or be less than 15 days.
To qualify for this option , the duration of the customer s high seasonal production cycle must be
6 months or less, and the average of the customer s monthly maximum demand during it's OBP
must be at least double the average of its monthly maximum demand during it's non-aSP period.
Customers may not discontinue this option before the end date of their OBP.
Prior to receiving OBP service, the customer shall sign the "Optimal Billing Period Service
Agreement," Form No. 14-689 and pay an OBP fee of $160.00 per meter. To continue service
under this special condition the customer must sign a new OBP Agreement and pay the OBP fee
each year.
This Special Condition shall expire upon implementation of tariff changes in SCE's 2003 General (T)Rate Case. (T)
21.Billing: 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.
Bundled Service Customers receive supply and delivery services solely from SCE.
The customer s bill is based on the total rates set forth above. The Procured Energy
(supply) component is equal to the Procured Energy (PE) Charge as set forth in
Schedule PE.
Direct Access Customers purchase energy from an Energy Service Provider and
continue receiving delivery services from SCE. The PE Charge is determined as
specified for a Bundled Service Customer. The customer s bill will be calculated as for
a Bundled Service Customer, but the customer will receive a credit for the PE Charge.
(Continued)
(To be inserted by utility)
Advice 1645-
Decision
Issued by
John R. Fielder
Senior Vice President
(To be inserted by Cal. PUC)
Date Filed Aug 16 2002
Effective Sep 25, 2002
Resolution12C10
~ EO"lSO'
~ ,O"ON ",,"NAT'ONAL
"'.,".,
Southern California Edison
Rosemead, California Cancelling
Revised
Revised
Cal. PUC Sheet No.
Cal. PUC Sheet No.
33257 -
30937-
Schedule TOU-
TIME-OF-USE - GENERAL SERVICE - LARGE
Sheet 13
(Continued)
SPECIAL CONDITIONS (Continued)
22.Generation Charge: The generation charge is calculated based on the total rate less the sum
of: Distribution , Transmission, Public Purpose Programs, Nuclear Decommissioning, and
Fixed Transition Amount (where applicable) charges , the Transmission Owners Tariff Charge
Adjustments (TOTCA), and the Public Utilities Commission Reimbursement Fee.
Customers with Service Metered and Delivered at Voltages above 50 kV (Sub-transmission
customers) Included in Rotating Outages.
(C)23.
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). 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
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.
Customer-Implemented Load Reduction.
(i)Notification of Required Load Reduction. At the direction of the ISO, 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.(C)
(Continued)
(T 0 be inserted by utility)
Advice 1693-
Decision
Issued by
John R. Fielder
Senior Vice President
(To be inserted by Cal. PUC)
Date Filed Mar 14, 2003
Effective May 15, 2003
Resolution13C25
E"oT SOA
'""0' """.mONAl. c.~,..,
Southern California Edison
Rosemead, California
Original Cal. PUC Sheet No.
Cal. PUC Sheet No.
33258-
Cancelling
Sheet 14Schedule TOU-
TIME-OF-USE - GENERAL SERVICE - LARGE
SPECIAL CONDITIONS (Continued)
(Continued)
23. Customers with Service Metered and Delivered at Voltages above 50 kV (Sub-transmission
customers) Included in Rotating Outages. (Continued)
(ii)
Customer-Implemented Load Reduction. (Continued)
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'
rotating outage notification and must be available to receive the notification atall 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 regularly scheduled meter read date following the applicable
rotating outage.
(iv)
For customers with net-generators, Excess Energy Charges shall not apply
during periods of verifiable scheduled generator maintenance or if the
customer s generator suffers a verified forced outage. The scheduled
maintenance must be approved in advance by both the ISO and SCE , but
approval ~ay not be unreasonably held.
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)
(T 0 be inserted by utility)
Advice 1693-
Decision
Issued by
John R. Fielder
Senior Vice President
(T 0 be inserted by Cal. PUC)
Date Filed Mar 14 , 2003
Effective May 15, 2003
Resolution14C20
roT soo
'"' 'D"D' ,,""mD'AL Com,..,Original Gal. PUG Sheet No. 33259-
Gal. PUG Sheet No.Southern California Edison
Rosemead, California Cancelling
Sheet 15Schedule TOU-
TIME-OF-USE - GENERAL SERVICE - LARGE
SPECIAL CONDITIONS (Continued)
(Continued)
23. Customers with Service Metered and Delivered at Voltages above 50 kV (Sub-transmission
customers) Included in Rotating Outages. (Continued)
SeE-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
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.
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
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)
(To be inserted by utility)
Advice 1693-
Decision
Issued by
John R. Fielder
Senior Vice President
(To be inserted by Gal. PUG)
Date Filed Mar 14, 2003
Effective May 15 , 2003
Resolution15C22
E:J EDT SOA,""ON 'NTUNAnONAL Co~,~,
Southern California Edison
Rosemead, California
Original Cal. PUC Sheet No. 33260-
Cal. PUC Sheet No.Cancelling
Schedule TOU-
TIME-OF-USE - GENERAL SERVICE - LARGE
Sheet 16
(Continued)
SPECIAL CONDITIONS (Continued)
23. Customers with Service Metered and Delivered at Voltages above 50 kV (Sub-transmission
customers) Included in Rotating Outages. (Continued)
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
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.
(Continued)
(T 0 be inserted by utility)
Advice 1693-
Decision
Issued by
John R. Fielder
Senior Vice President
(To be inserted by Cal. PUC)
Date Filed Mar 14 , 2003
Effective May 15, 2003
Resolution16C14
E"oT sON
ED"DN "",,"AT'DN,,"
~.,..,
Southern California Edison
Rosemead, California Cancelling
Revised
Revised
Cal. PUC Sheet No.
Cal. PUC Sheet No.
33261-
33116-
Schedule TOU-
TIME-OF-USE - GENERAL SERVICE - LARGE
Sheet 17 (T)
RATE COMPONENTS
(Continued)
Rate Com onents Table
Rate Schedule Summary
Below 2 kV
Energy Charge - $/kWh
Summer Season
On-Peak 00000 00226
Mid-peak 00000 00226
Oft-Peak 00000 00226
Winter Season
On-Peak
Mid-peak 00000 00226
Oft-Peak 00000 00226
Customer Charge - $/month 191,
Facilities Related
Demand Charge - $/kW
Time Related
Demand Charge. $/kW
Summer
On-Peak
Mid-Peak
Oft-Peak
Winter
On-Peak
Mid-Peak
Oft-Peak
N/A
Depl. of Water Resources (DWR)
Procurement Charge-$/kWh
19120 00045 00260 00011 00031 00513 20206
09953 00045 00260 00011 00031 00513 11039
07774 00045 00260 00011 00031 00513 08860
N/A N/A N/A N/A N/A N/A
11300 00045 00260 00011 00031 00513 12386
07889 00045 00260 00011 00031 00513 08975
107.298.
10.17.
N/A N/A N/A
09472 09472
1 Trans = Transmission
2 Distrbtn = Distribution
3 Gen = Generation
4 NDC = Nuclear Decommissioning Charge
5 PPPC = Public Purpose Programs Charge (includes California Alternate Rates for Energy Surcharge where applicable.
6 TOTCA = Transmission Owners Tarift Charge Adjustments (FERC approved - represents Transmission Revenue Balancing Account Adjustment
(TRBAA) of negative $0,00053 per kWh, Reliability Services Balancing Account Adjustment (RSBAA) of $0.00037 per kWh, and Transmission Access
Charge Balancing Account Adjustment (T ACBAA) of $0,00027 per kWh).
7 PUCRF = The PUC Reimbursement Fee is described in Schedule RF-
. DWRBC = Department of Water Resources (DWR) Bond Charge, The DWR Bond Charge is currently not applicable to Direct Access Customers.
Pursuant to D,02-10-063 and D.02-02-051 , bond charges may be collected from Direct Access Customers when a decision in R02-01-011
becomes final and unappealable.
(To be inserted by utility)
Advice 1693-
Decision
17C20
(Continued)
Issued by
John R. Fielder
Senior Vice President
(To be inserted by Cal. PUG)
Date Filed Mar 14, 2003
Effective May 15, 2003
Resolution
roT SOA
Southern California Edison
Rosemead, California Cancelling
Revised
Revised
Cal. PUC Sheet No.
Cal. PUC Sheet No.
33262-
33117-
,""ON 'NTUNAT'ONAL c.mp~,
Schedule TOU-
TIME-OF-USE - GENERAL SERVICE - LARGE
Sheet 18 (T)
(Continued)
RATE COMPONENTS (Cont'd)
Rate Schedule Summary
From 2 kV to 50 kV
Energy Charge - $lkWh
Summer Season
On-Peak 00000 00197 18515 00040 00240 00008 00031 00513 19544
Mid-peak 00000 00197 09868 00040 00240 00008 00031 00513 10897
Off-Peak 00000 00197 07779 00040 00240 00008 00031 00513 08808
Winter Season
On-Peak NIA N/A N/A NIA NIA NIA
Mid-peak 00000 00197 11092 00040 00240 00008 00031 00513 12121
Off-Peak 00000 00197 07895 00040 00240 00008 00031 00513 08924
Customer Charge - $Imonth 191.107.299.
Facilities Related
Oemand Charge - $IKw
Time Related
Demand Charge. $lkW
Summer
On-Peak 10.17.
Mid-Peak
Off-Peak
Winter
On-Peak NIA NIA NIA NIA
Mid-Peak
Off-Peak
Rate Com onents Table
Dept. of Water Resources (DWR)
Procurement Charge-$lkWh
1 Trans = Transmission
2 Distrbtn = Distribution
3 Gen = Generation
4 NDC = Nuciear Decommissioning Charge
5 PPPC = Public Purpose Programs Charge (includes California Alternate Rates for Energy Surcharge where applicable.
. TOTCA = Transmission Owners Tariff Charge Adjustments (FERC approved - represents Transmission Revemje Balancing Account Adjustment
(TRBAA) of negative $0.00053 per kWh. Reliability Services Balancing Account Adjustment (RSBAA) of $0.00034 per kWh, and Transmission
Access Charge Balancing Account Adjustment (T ACBAA) of $0.00027 per kWh),
7 PUCRF = The PUC Reimbursement Fee is described in Schedule RF-
8 DWRBC = Department of Water Resources (DWR) Bond Charge. The DWR Bond Charge is currently not applicable to Direct Access Customers.
Pursuant to D,02-10-063 and 0,02-02-051 . bond charges may be collected from Direct Access Customers when a decision in R.O2-01-011
becomes final and unappealable.
09472 09472
(Continued)
(To be inserted by utility)
Advice 1693-
Decision
Issued by
John R. Fielder
Senior Vice President
(To be inserted by Cal. PUG)
Date Filed Mar 14, 2003
Effective May 15, 2003
Resolution1BC20
EDT so'
'O"OH """HAT,"H""
~.,.",
Southern California Edison
Rosemead, California
RATE COMPONENTS (Cont'd)
Cancelling
Revised
Revised
Cal. PUC Sheet No.
Cal. PUC Sheet No.
33263-
33118-
Schedule TOU-
TIME-OF-USE - GENERAL SERVICE - LARGE
Sheet 19 (T)
(Continued)
Rate Com onents Table
Rate Schedule Summary
Above 50 kV
Energy Charge - $/kWh
Summer Season
On-Peak 00000 00062 17483 00024 00177 00002 00031
Mid-peak 00000 00062 09154 00024 00177 00002 00031
Off-Peak 00000 00062 07856 00024 00177 00002 00031
Winter Season
On-Peak N/A N/A N/A N/A
Mid-peak 00000 00062 10194 00024 00177 00002 00031
Off-Peak 00000 00062 07973 00024 00177 00002 00031
Customer Charge - $/month
Facilities Related
Demand Charge - $/kW
Time Related
Demand Charge - $/kW
Summer On-Peak
Mid-Peak
Off-Peak
Winter On-Peak
Mid-Peak
Off-Peak
Dept. of Water Resources (DWR)
Procurement Charge-$/kWh
224.125.
00513 18292
00513 09963
00513 08665
N/A
00513 11003
00513 08782
349.
0.46
N/A N/A N/A
09472
13,
N/A
09472
1 Trans = Transmission
2 Distrbtn = Distribution
3 Gen = Generation
4 NDC = Nuciear Decommissioning Charge
5 PPPC = Public Purpose Programs Charge (includes California Alternate Rates for Energy Surcharge where applicable.
6 TOTCA = Transmission Owners Tariff Charge Adjustments IFERC approved - represents Transmission Revenue Balancing Account Adjustment
(TRBAA) of negative $0,00053 per kWh, Reliability Services Balancing Account Adjustment (RSBAA) of $0,00028 per kWh, and Transmission
Access Charge Balancing Account Adjustment (TACBAA) of $0,00027 per kWh!,
7 PUCRF = The PUC Reimbursement Fee is described in Schedule RF-
5 DWRBC = Department of Water Resources (DWR) Bond Charge, The DWR Bond Charge is currently not applicable to Direct Access Customers.
Pursuant to 0.02-10-063 and 0.02-02-051, bond charges may be collected from Direct Access Customers when a decision in R02-01-011
becomes final and unappealable,
(To be inserted by utility)
Advice 1693-
Decision
(Continued)
Issued by
John R. Fielder
Seri'ior Vice President
(T 0 be inserted by Cal. PUC)
Date Filed Mar 14, 2003
Effective May 15, 2003
Resolution19C20
I &Pacific Gas and Electric Company
San Francisco, Galifornia
Cancelling
Revised
Revised
Gal. P.C. Sheet No.
Gal. P.C. Sheet No.
19797 -
19205-
COMM E RC IAL/INDUSTRIAL/GE NE RAL
SCHEDULE E-19-MEDIUM GENERAL DEMAND-METERED TIME-OF-USE SERVICE
CONTENTS:This rate schedule is divided into the following sections:
Applicability 13.Common-Area Accounts (N)
Territory 14.Contracts (T)
Firm Service Rates 15.Voluntary Service Provisions
Definition Of Service Voltage 16.Billing
Definition Of Time Periods 17.Rate Reduction Bond Credit
Power Factor Adjustments 18.CARE Discount for Nonprofit (T)
Charges For Transformer Losses Group-Living Facilities
Special Facilities 19,Optional Optimal Billing Period (T)
10.Arrangements For Visual-Display Service
Metering 20.Optional Optimal Billing Period (T)
11.Non-Firm Service Program Service (T)
12.Non-Firm Service Rates 21.Electric Emergency Plan Rotating (N)
Block Outages (N)
1. APPLICABILITY:Initial Assignment: A customer must take service under Schedule E-19 if: (1) the
customer s load does not meet the Schedule E-20 requirements, but, (2) the
customer s maximum billing demand (as defined below) has exceeded 499 kilowatts
for at least three consecutive months during the most recent 12-month period
(referred to as Schedule E-19). If 70 percent or more of the customer s energy use is
for agricultural end-uses, the customer will be served under an agricultural schedule.
Schedule E-19 is not applicable to customers for whom residential service would
apply, (see except for single-phase and polyphase service in common areas in a
multifamily complex (see Common-Area Accounts section).
(T)
(T)
Customer accounts which fail to qualify under these requirements will be evaluated
for transfer to service under a different applicable rate schedule.
The provisions of Schedule S-Standby Service Special Conditions 1 through 6 shall
also apply to customers whose premises are regularly supplied in part (but not in
whole) by electric energy from a nonutility source of supply. These customers will pay
monthly reservation charges as specified under Section 1 of Schedule S in addition to
all applicable Schedule E-19 charges. Customers who utilize solar generating
facilities which are less than or equal to one megawatt to serve load and who do not
sell power or make more than incidental export of power into PG&E's power grid and
who have not elected service under Schedule E-NET, will be exempt from paying
standby charges under this provision. Any customer under a time-of-use rate
schedule using electric generation technology that meets the criteria as defined in
Electric Rule 1 for Distributed Energy Resources is exempt from the otherwise
applicable Standby Reservation Charges. Customers qualifying for this exemption
shall be subject to the requirements outlined in Section 20 of this tariff.
Voluntary E-19 Service: This schedule is available on a voluntary basis for
customers with maximum billing demands less than 500 kW. Customers voluntarily
taking service on this schedule are subject to all the terms and conditions below
unless otherwise specified in Section 15.
47818
Issued by
Karen A. Tomca/a
Vice President
Regulatory Relations
Date Filed
Effective
Resolution No.
(Continued)
February 14. 2003
Januarv 16. 2003Advice Letter No. 2344-
Decision No. 03-01-037
Pacific Gas and Electric Company
San Francisco, California
Cancelling
Revised
Revised
Gal. P.C. Sheet No.
Gal. P. U. C. Sheet No.
17092-
15316-
COMME RC IALII N 0 USTR IALIG E N ERAL
SCHEDULE E-19-MEDIUM GENERAL DEMAND-METERED TIME-OF-USE SERVICE
(Continued)
1. APPLICABILITY:
(Cont'd.
Depending upon whether or not an Installation or Processing Charge applies, the
customer will be served under one of these rates under Schedule E-19:
Rate V:Applies 1) to customers have who are served under Schedule E-
Voluntary prior to January 1 , 1996, and have not changed rate
schedules since that time, or 2) to customers transferring from
Schedule E-19 mandatory or E-20, or 3) to customers whose service
has an existing and appropriate time-of-use meter installed and that
initiated service on this schedule during 1996, or 4) to customers who
signed an "Incentive Program Prescriptive Performance Off-Peak
Cooling Application" with PG&E prior to January 1, 1996, in order to
install a thermal energy storage system and now are about to operate
that system.
RateW:Applies to customers whose account does not have an appropriate
time-of-use meter. The customer must pay an "Installation Charge
prior to taking service under this schedule,
Rate X:Applies to customers whose account has an appropriate time-of-use
meter, but is not currently being served under this schedule. The
customer will be required to pay a "Processing Charge" prior to taking
service under this schedule.
(T)
Transfers Off of Schedule E-19: If a customer s maximum demand has failed to
exceed 499 kilowatts for 12 consecutive months, PG&E will transfer that customer
account to voluntary E-19 service or to a different applicable rate schedule.
Assignment of New Customers: If a customer is new and PG&E believes that the
customer s maximum demand will be 500 through 999 kilowatts and that the
customer should not be served under a time-of-use agricultural schedule, PG&E will
serve the customer s account under Schedule E-19.
Definition of Maximum Demand: Demand will be averaged over 30-minute intervals
for customers whose maximum demand exceeds 499 kW. "Maximum demand" will
be the highest of all the 30-minute averages for the billing month. If the customer
use of electricity is intermittent or subject to violent fluctuations, a 5-minute or 15-
minute interval may be used instead of the 30-minute interval. If the customer has
any welding machines, the diversified resistance welder load, calculated in
accordance with Section J of Rule 2 , will be considered the maximum demand if it
exceeds the maximum demand that results from averaging the demand over 30-
minute intervals. The customer s maximum-peak-period demand will be the highest
of all the 30-minute averages for the peak period during the billing month. (See
Section 5 for a definition of "Peak-Period.) See Section 15 for the definition of
maximum demand for customers voluntarily selecting E-19.
(D)
Advice Letter No.
Decision No.
2013-Issued by
DeAnn Hapner
Vice President
Regulatory Relations
Date Filed
Effective
Resolution No.
(Continued)
June 29. 2000
AuQust 8. 2000
42260
Pacific Gas and Electric Company
San Francisco, California
Cancelling
Original
Revised
Cal. P.C. Sheet No.
Cal. P.C. Sheet No.
17093-
15317-
1. APPLICABILITY:
(Cont'd.
2. TERRITORY:
Advice Letter No.
Decision No.
42261
COMM ERCIALIIN DUSTRIAL/GENE RAL
SCHEDULE E-19-MEDIUM GENERAL DEMAND-METERED TIME-OF-USE SERVICE
(Continued)
Standby Demand: For customers for whom Schedule S-Standby Service Special
Conditions 1 through 6 apply, standby demand is the portion of a customer
maximum demand in any month caused by nonoperation of the customer s alternate
source of power, and for which a demand charge is paid under the regular service
schedule.
If the customer imposes standby demand in any month, then the regular service
maximum demand charge will be reduced by the applicable reservation capacity
charge (see Schedule S Special Condition 1).
To qualify for the above reduction in the maximum demand charge, the customer
must, within 30 days of the regular meter-read date , demonstrate to the satisfaction
of PG&E the amount of standby demand in any month. This may be done by
submitting to PG&E a completed Electric Standby Service Log Sheet (Form 79-726).
This rate schedule applies everywhere PG&E provides electricity service.
2013-Issued by
DeAnn Hapner
Vice President
Regulatory Relations
Date Filed
Effective
Resolution No.
(T)
(Continued)
June 29. 2000
AuQust 8. 2000
Revised Cal. P.C. Sheet No.20719-
Pacific Gas and Electric Company Cancelling Revised Cal. P.C. Sheet No.20548-
San Francisco, California
COM MER C IALII N DU ST RIALIG ENE RAL
SCHEDULE E-19-MEDIUM GENERAL DEMAND. METERED TIME-OF-USE SERVICE
(Continued)
FIRM SERVICE RATES: (Cont'd.
Public Nuclear Reliabilil
Trans-Dislribu-Purpose Genera-Decom-DWR Tolal
SECONDARY (E-19S)missIOn tion Pro9rams lion mlssiomn9 FTA Services Bond Rate
Demand Charges (per kW)
Maximum Peak-Period Demand
Summer 98 (I)37 (R)13,
Winter
Maximum Part-Peak.Period
Demand
Summer 66 (I)04 (R)
Winter 63 (I)02 (R)
Maximum Demand
Summer 2.41 71 (I)(2.72) (R)
Winter 2.41 71 (I)(2.72) (R)
Energy Charges (per kWh)
Peak.Period
Summer 00804 (I)00350 16196 (I)00036 01013 00444 (R)18843
Winter
Parl-Peak-Period
Summer 00532 (I)00350 08566 (I)00036 01013 00444 (R)10941
Winter 00585 (I)00350 09095 (I)00036 01013 00444 (R)11523
Off.Peak.Period
Summer 00463 (I)00350 06884 (I)00036 01013 00444 (R)09190
Winter 00461 (I)00350 06865 (I)00036 01013 00444 (R)09169
Average Rate limiter
(per kWh in summer months)
14043
Peak Period Rate limiter
(per kWh in summer months)
97773
Customer Charge
(per meter per day)
74949 74949
Rate V 66119 66119
Rate W 50349 50349
Rate X 66119 66119
Installation Charge
(One.time charge per meter)443,443.
Processing Charge
(One.lime charge per meter)87,87.
TransmIssion Revenue
Balancing Account
Adjustment Rate
per kWh (0,00230)00230 00000
Advice LetterNo.
Decision No.
2424-Issued by
Karen A. Tomcala
Vice President
Regulatory Relations
Date Filed
Effective
Resolution No.
(Continued)
SeDtember 23. 2003
October 1. 2003
49213
Revised Cal. P.C. Sheet No.20720-
Pacific Gas and Electric Company Cancelling Revised Cal. P.C. Sheet No.20549-
San Francisco, California
COMMERC IALIINDUSTRIAL/GE NE RAL
SCHEDULE E-19-MEDIUM GENERAL DEMAND-METERED TIME-OF-USE SERVICE
(Continued)
FIRM SERVICE RATES (Cont'd.
Public Nuclear
Trans-Distribu-Purpose Genera.Decom-Reliability DWR Total
PRIMARY (E-19P)mission tion Programs tion misslonmg FTA Services Bond Rate
Demand Charges (per kW)
Maximum Peak-Period Demand
Summer 62 (R)18 (I)11.
Winter
Maximum Part-Peak-Period
Demand
Summer 81 (R)84 (I)
Winter 81 (R)84 (I)
Maximum Demand
Summer 2.41 06 (R)(2,07) (I)
Winter 06 (R)(2.07) (I)
Energy Charges (per kWh)
Peak-Period
Summer 00269 (R)00322 14394 (I)00031 01013 00444 (R)18473
Winter
Part-peak-Period
Summer 00209 (R)00322 07980 (I)00031 01013 00444 (R)09999
Winter 00245 (R)00322 08776 (I)00031 01013 00444 (R)10831
Off-Peak-Period
Summer 00202 (R)00322 06802 (I)00031 01013 00444 (R)08814
Winter 00204 (R)00322 06899 (I)00031 01013 00444 (R)08913
Average Rate Limiter
(per kWh in summer months)14043
Peak Period Rate Limiter
(per kWh in summer months)84937
Customer Charge
(per meter per day)
59959 59959
Rate V 66119 66119
Rate W 50349 50349
Rate X 66119 66119
Installation Charge
(One-time charge per meter)443,443.
Processing Charge
(One-time charge per meter)87,87.
Transmission Revenue
Balancing Account
Adjustment Rate
per kWh per month (0,00230)00230 00000
Advice Letter No.
Decision No.
2424-Issued by
Karen A. Tomcala
Vice President
Regulatory Relations
Date Filed
Effective
Resolution No.
(Continued)
September 23. 2003
October 1. 2003
49214
Revised Ca/. P.C. Sheet No.20721-
Pacific Gas and Electric Company Cancelling Revised Ca/. P.C. Sheet No.20550-
San Francisco, California
COMM E RC IALIINDUST RIAL/GENERAL
SCHEDULE E-19-MEDIUM GENERAL DEMAND-METERED TIME-OF-USE SERVICE
(Continued)
FIRM SERVICE RATES (Cont'd.
Public Nuclear
Trans-Distribu-Purpose Genera-Decom-Reliability DWR Total
TRANSMISSION (E-19T)missIon tion Programs tion mlssionmg FTA Services Bond Rate
Demand Charges (per kW)
Maximum Peak-Period
Demand
Summer
Winter
Maximum Part-Peak-Period
Demand
Summer
Winter
Maximum Demand
Summer 2.41 04 (R)(3,25) (I)
Winter 04 (R)(3,25) (I)
Energy Charges (per kWh)
Peak-Period
Summer 00512 (R)00326 16224 (I)00032 01013 00444 (R)18551
Winter
Part-Peak-Period
Summer 00389 (R)00326 09507 (I)00032 01013 00444 (R)11711
Winter 00479 (R)00326 10951 (I)00032 01013 00444 (R)13245
Off-Peak-Period
Summer 00365 (R)00326 08131 (I)00032 01013 00444 (R)10311
Winter 00395 (R)00326 08600 (I)00032 01013 00444 (R)10810
Average Rate Limiter
(per kWh in summer months)
Peak Period Rate Limiter
(per kWh in summer months)
58676
Customer Charge
(per meter per day)
20,04107 20,04107
Rate V 66119 66119
Rate W 50349 50349
Rate X 66119 66119
Installation Charge
(One-time charge per meter)443,443,
Processing Charge
(One-time charge per meter)87,87.
Transmission Revenue
Balancing Account
Adjustment Rate
per kWh per month (0,00230)00230 00000
Advice Letter No.
Decision No.
2424-Issued by
Karen A. Tomcala
Vice President
Regulatory Relations
Date Filed
Effective
Resolution No.
(Continued)
SeDtember 23. 2003
October 1. 2003
49215
I &Pacific Gas and Electric Company
San Francisco, California
Cancelling
Revised
Revised
Cal. P.C. Sheet No.
Cal. P.C. Sheet No.
19997 -
19695-
COMMERCIAL/INDUSTRIAL/GENERAL
SCHEDULE E-19-MEDIUM GENERAL DEMAND-METERED TIME-OF-USE SERVICE
(Continued)
3. FIRM SERVICE
RATES:
(Conrd.
Total rates include the applicable Energy Procurement Surcharges (EPS) listed in
Schedule E-EPS. Generation is calculated residually based on the total rate less the
sum of: Distribution, Transmission , Reliability Services, Public Purpose Program
Nuclear Decommissioning, Department of Water Resources (UDWR Bond") (where
applicable), and FT A (where applicable).
The above rate components apply to those customers eligible for the Rate Reduction
Bond Credit. For those ineligible for the credit, the Generation component will be
equal to the Generation component listed above plus the FTA component.
TYPES OF CHARGES: The customer s monthly charge for service under
Schedule E-19 is the sum of a customer charge , demand charges, and energy
charges:
The customer charge is a flat monthly fee.
This schedule has three demand charges, a maximum-peak-period-
demand charge , a maximum part-peak-period and a maximum-demand
charge. The maximum-peak-period-demand charge per kilowatt applies to
the maximum demand during the month's peak hours, the maximum part-
peak-period demand charge applies to the maximum demand during the
month's part-peak hours , and the maximum demand charge per kilowatt
applies to the maximum demand at any time during the month. The bill will
include ill! of these demand charges. (Time periods are defined in
Section 5.
The energy charge is the sum of th e energy charges from the peak
partial-peak , and off-peak periods. The customer pays for energy by the
kilowatt-hour (kWh), and rates are differentiated according to time of day
and time of year.
If applicable, alilnstaJlation or Processing Charges must be paid in one
lump sum before the customer can take service under this rate schedule.
Payments for these charges are not transferable to another service or
refundable, in whole or part. PG&E will place the account on this schedule
within four weeks of receiving payment from the customer. The meters
required for this schedule may become obsolete as a result of electric
industry restructuring or other action by the California Public Utilities
Commission. Therefore, any and all risks of paying the required charges
and not receiving commensurate benefit are entirely that of the customer.
The monthly charges may be increased or decreased based upon the
power factor. (See Section 6.
As shown on the rate chart, which set of customer, demand, and energy
charges is paid depends on the level of the customers maximum demand
and the voltage at which service is taken. Service voltages are defined in
Section 4 below,
Please note that the rates in the table above apply only to firm service.
Rates for non-firm service can be found in Section 12 of this rate schedule.
Customers participating in the Nonfirm Bidding Pilot Program will be billed
according to Section 19. Customers participating in the local Nonfirm
Bidding Pilot Program will be billed according to Section 20.
Advice Letter No. 2364-
Decision No. 02-12-082
Issued by
Karen A. Tomcala
Vice President
Regulatory Relations
Date Filed
Effective
Resolution No.
(T)
(T)
(Continued)
April 1. 2003
April 1 . 2003
48083
Pacific Gas and Electric Company
San Francisco, California
Cancelling
Revised
Revised
Cal. P.C. Sheet No.
Gal. P.C. Sheet No.
20722-
19998-
COM M E RC IALII N DUST R IAL/G E NE RAL
SCHEDULE E-19-MEDIUM GENERAL DEMAND-METEREDTIME-OF-USE SERVICE
(Continued)
3. FIRM SERVICE
RATES:
(Cont'
4. DEFINITION OF
SERVICE
VOLTAGE:
5. DEFINITION OF
TIME PERIODS:
Advice Letter No.
Decision No.
49216
AVERAGE RATE LIMITER (applies to bundled, firm service only): If the
customer takes service on Schedule E-19 in either the secondary or primary
voltage class, bills will be controlled by a "rate limiter" during the summer
months. The bill will be reduced if necessary so that the average rate paid for
all demand and energy charges less the EPS amount calculated using the
applicable rates provided in Schedule E-EPS during a summer month does not
exceed the average rate limiter shown on this Schedule. This provision will not
apply if the customer has elected to receive separate billing for back-up and
maintenance service under Special Condition 8 of Schedule S.
Reductions in revenue resulting from application of the average rate limiter will
be reflected as reduced distribution amounts for billing purposes.
PEAK-PERIOD RATE LIMITER (applies to bundled, firm service only): If the
customer takes service on Schedule E-19 at any service voltage level, bills will
be controlled by a "peak-period rate limiter" during the summer months. The
bill will be reduced if necessary so that the average rate paid for all on-peak
demand and energy charges less the peak period EPS amount calculated
using the applicable rates provided in Schedule E-EPS during the peak period
in a summer month does not exceed the peak-period rate limiter shown on this
schedule. This provision will not apply if the customer has elected to receive
separate billing for back-up and maintenance service under Special Condition
8 of Schedule S.
Reductions in revenue resulting from application of the peak-period rate limiter
will be reflected as reduced distribution amounts for billing purposes.
The following defines the three voltage classes of Schedule E-19 rates. Standard
Service Voltages are listed in Rule 2 , Section B.
Secondary: This is the voltage class if the service voltage is less than
2,400 volts or if the definitions of "primary" and "transmission" do not apply to
the service.
Primary: This is the voltage class if the customer is served from a "single
customer substation" or without transformation from PG&E's serving
distribution system at one of the standard primary voltages specified in PG&E'
Electric Rule 2, Section B.
Transmission: This is the voltage class if the customer is served without
transformation from PG&E's serving transmission system at one of the
standard transmission voltages specified in PG&E's Rule 2, Section B.
Times of the year and times of the day are defined as follows:
SUMMER Period A. (Service from May 1 through October 31):
Peak:12:00 noon. to 6:00 p,Monday through Friday.
Partial-peak:8:30 a.m. to 12:00 noon AND 6:00 p.m. to 9:30 p.m. Monday through
Friday (except holidays).
Off-peak:9:30 p.m. to 8:30 a.
Allday
Monday through Friday
Saturday, Sunday, and holidays
(T)
(T)
(T)
(T)
2424-Issued by
Karen A. Tomcala
Vice President
Regulatory Relations
Date Filed
Effective
Resolution No.
(Continued)
September 23.2003
October 1. 2003
Pacific Gas and Electric Company
San Francisco, California
Cancelling
Revised
Revised
Cal. P.C. Sheet No.
Cal. P. U. C. Sheet No.
20723-
19999-
5. DEFINITION OF
TIME PERIODS:
(Cont'd.
6. POWER FACTOR
ADJUSTMENTS:
7. CHARGES FOR
TRANSFORMER
AND LINE
LOSSES:
Advice Letter No.
Decision No.
49217
COMM E RCIALIINDUSTRIAL/GE NE RAL
SCHEDULE E-19-MEDIUM GENERAL DEMAND-METERED TIME-OF-USE SERVICE
(Continued)
WINTER Period B (service from November 1 through April 30):
Partial-Peak:8:30 a.m. to 9:30 p.Monday through Friday (except holidays).
Monday through Friday (except holidays).
Saturday, Sunday, and holidaysOff-Peak:9:30 p.m. to 8:30 a.
All day
HOLIDAYS: "Holidays" for the purposes of this rate schedule are New Year s Day,
President's Day, Memorial Day, Independence Day, Labor Day, Veterans Day,
Thanksgiving Day, and Christmas Day. The dates will be those on which the
holidays are legally observed.
CHANGE FROM SUMMER TO WINTER OR WINTER TO SUMMER: When a billing
month includes both summer and winter days, PG&E will calculate demand charges
as follows. It will consider the applicable maximum demands for the summer and
winter portions of the billing month separately, calculate a demand charge for each,
and then apply the two according to the number of billing days each represents.
Bills will be adjusted based on the power factor for all customers except those
selecting voluntary E-19 service. The power factor is computed from the ratio of
lagging reactive kilovolt-ampere-hours to the kilowatt-hours consumed in the month.
Power factors are rounded to the nearest whole percent.
The rates in this rate schedule are based on a power factor of 85 percent. If the
average power factor is greater than 85 percent, the total monthly bill will be reduced
by 0.06 percent of the bundled service bill less any taxes and the EPS amount
calculated using applicable rates provided in Schedule E-EPS for each percentage
point above 85 percent. If the average power factor is below 85 percent, the total
monthly bill of the bundled service bill less any taxes and the EPS amount calculated
using applicable rates provided in Schedule E-EPS will be increased by 0.06 percent
for each percentage point below 85 percent.
Power factor adjustments will be assigned to distribution for billing purposes.
The demand and energy meter readings used in determining the charges will be
adjusted to correct for transformation and line losses in accordance with Section B.4
of Rule 2.
(T)
2424-Issued by
Karen A. Tomcala
Vice President
Regulatory Relations
Date Filed
Effective
Resolution No.
(Continued)
September 23.2003
October 1 . 2003
I &Pacific Gas and Electric Company
San Francisco, California
Cancelling
Revised
Revised
Cal. P.C. Sheet No.
Cal. P.C. Sheet No.
18037-
18002-
8. STANDARD
SERVICE
FACILITIES:
9. SPECIAL
FACiliTIES:
10. ARRANGE-
MENTS FOR
VISUAL-
DISPLAY
METERING:
11. NON-FIRM
SERVICE
PROGRAM:
COMM E RCIALlINDUSTRIAL/GENERAl
SCHEDULE E-19-MEDIUM GENERAL DEMAND-METERED TIME-OF-USE SERVICE
(Continued)
If PG&E must install any new or additional facilities to provide the customer with
service under this schedule the customer may have to pay some of the cost. Any
advance necessary and any monthly charge for the facilities will be specified in a line
extension agreement. See Rules 2, 15, and 16 for details. This section does not
apply to customers voluntarily taking service under Schedule E-1 9.
Facilities installed to serve the customer may be removed when service is
discontinued. The customer will then have to repay PG&E for all or some of its
investment in the facilities. Terms and conditions for repayment will be set forth in
the line extension agreement.
PG&E will normally install only those standard facilities it deems necessary to
provide service under this schedule. If the customer requests any additional
facilities , those facilities will be treated as "special facilities" in accordance with
Section I of Rule 2.
If the customer wishes to have visual-display metering equipment in addition to the
regular metering equipment, and the customer would like PG&E to install that
equipment, the customer must submit a written request to PG&E. PG&E will provide
and install the equipment within 180 days of receiving the request. The visual-
display metering equipment will be installed near the present metering equipment.
The customer will be responsible for providing the required space and associated
wiring.
PG&E will continue to use the regular metering equipment for billing purposes.
As noted , the rates in the chart in Section 3 of this rate schedule apply to firm service
only. ("Firm" means service where PG&E provides a "continuous and sufficient
supply of electricity," as described in Rule 14.) A customer may also elect to receive
non-firm service under Schedule E-19. Non-firm service is not available to
customers taking service under Schedule E-19 on a voluntary basis. Customers
participating in the Nonfirm bidding Pilot should refer to Section 19. Customers
participating in the Local Nonfirm Bidding Pilot should refer to Section 20.
The Non-firm Service Program is closed to existing customers. The customer s total
load must meet the eligibility criteria in 11.a in order to participate in the Non-firm
Service Program. Customers being served , as of December 31 , 1992, under the
Non-firm Service Program may continue to participate in the Non-firm Service
Program.
Advice Letter No. 2099-
Decision No. 01-04-006
Issued by
DeAnn Hapner
Vice President
Regulatory Relations
Date Filed
Effective
Resolution No.
44228
(D)
(Continued)
April 17.2001
April 19.2001
I &Pacific Gas and Electric Company
San Francisco, California
Cancelling
Revised
Revised
Cal. P. C. Sheet No.
Cal. P.C. Sheet No.
18864-
17897,
18038-
11. NON-FIRM
SERVICE
PROGRAM:
(Cont'd.
COMM E RCIAL/IN DUSTRIAL/GENE RAL
SCHEDULE E-19-MEDIUM GENERAL DEMAND-METERED TIME-OF-USE SERVICE
(Continued)
This program is available for qualifying customers until modified or terminated in the
rate design phase of the next general rate case or similar proceeding as ordered in
Decision 02-04-060.
A customer who elects to receive non-firm service under Schedule E-19 must
participate in PG&E's Emergency Curtailment Program. A non-firm service customer
may also elect to participate in PG&E's Underfrequency Relay (UFR) program.
EMERGENCY CURTAILMENT PROGRAM: Under the Emergency Curtailment
Program, a non-firm service customer may be requested to reduce demand to a
designated number of kilowatts, referred to as the customer s contractual "firm
service level." PG&E will make requests for such curtailments from its non-firm
service customers upon notification from the California Independent System
Operator (ISO) that a system-wide or local operating condition exists which will
impair the ability of the ISO to meet the demands of PG&E's other customers. The
ISO is expected to issue load curtailment directives to PG&E in those instances
where load reductions are necessary in order to maintain system-wide operating
reserves above the 5 percent level throughout the next operating hour, or if such load
reductions are the sole remaining measure available in order to mitigate
transmission overloads in the PG&E area.
Advice Letter No. 2234-
Decision No. 02-04-060
Issued by
Karen A. Tomca/a
Vice President
Regulatory Relations
Date Filed
Effective
Resolution No.
46221
(D)
(D)
(N)
(N)
(Continued)
Mav 6. 2002
Mav 7.2002
I &Pacific Gas and Electric Company
San Francisco, California
Cancelling
Revised
Revised
Gal. C. Sheet No.
Gal. C. Sheet No.
18039-
18004-
11. NON-FIRM
SERVICE
PROGRAM:
(Cont'd.
COMM ERCIALIIN DUSTRIAL/GENERAL
SCHEDULE E-19-MEDIUM GENERAL DEMAND-METERED TIME-OF-USE SERVICE
(Continued)
UNDERFREOUENCY RELAY PROGRAM: Under this program, the customer agrees
to be subject at all times to automatic interruptions of service caused by an
underfrequency relay device that may be installed by PG&E.
See Section 13 of this rate schedule for a discussion of contractuallength-of-service
requirements that may be applied to customers enrolling in the Non-firm Service
Program. Please note that PG&E may require up to three years' written notice for a
change from non-firm to firm service , or for termination of participation in the
Underfrequency Relay Program.
ELIGIBILITY CRITERIA FOR NON-FIRM SERVICE: To qualify for non-firm service,
the customer must have had an average peak-period demand of at least
500 kilowatts during each of the last six summer billing months prior to the
customer s application for non-firm service. (Average peak-period demand is the
total number of kWh used during the peak-period hours of a billing month divided
by the total number of peak-period hours in the month.) Customers who have
not yet had six months of summer service must demonstrate to PG&E'
satisfaction that they will maintain an average monthly-peak-period demand of
500 kW or more to qualify for non-firm service.
Customers on non-firm service may not have, or obtain , any insurance for the
sole purpose of paying non-compliance penalties for willful failure to comply with
requests for curtailments. Customers with such policy will be terminated from
the Program , and will be required to pay back any incentives that the customer
received 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 the
program.
Customers who are deemed essential under the Electric Emergency Plan as
adopted in Decision 01-04-006 and Rulemaking 00-10-002 , must submit to
PG&E a written declaration that states that the customer is, to the best of that
customer s understanding, an essential customer under Commission rules and
exempt from rotating outages. It must also state that the customer voluntarily
elects to participate in an interruptible program for part of its load based on
adequate backup generation or other means to interrupt load upon request by
the respondent utility, while continuing to meet its essential needs. In addition,
an essential customer may commit no more than 50% of its average peak load
to interruptible programs.
Advice Letter No. 2099-
Decision No. 01-04-006
Issued by
DeAnn Hapner
Vice President
Regulatory Relations
Date Filed
Effective
Resolution No.
44230
(N)
(N)
(N)
(N)
(L)
(L)
(Continued)
April 17.2001
April 19,2001
I &Pacific Gas and Electric Company
San Francisco, California
Original Cal. P.C. Sheet No.
Cal. P.C. Sheet No.Cancelling
COM MER C IALII N DUSTRIAL/GE N E RAL
SCHEDULE E-19-MEDIUM GENERAL DEMAND-METERED TIME-OF-USE SERVICE
(Continued)
11. NON-FIRM
SERVICE
PROGRAM:
(Cont'd.
DESIGNATION OF FIRM SERVICE LEVEL: If a customer takes non-firm service,
the designated number of kilowatts to which the customer must reduce demand
during emergency curtailments is the customer s contractual "firm service leveL"
This designated firm service level must be at least 500 kilowatts less than the
smallest of the customer s average peak-period demands during the last
six summer billing months prior to the designation.
PRE-EMERGENCY CURTAILMENT REQUIREMENTS: A customer may be
requested to curtail , on a pre-emergency basis, up to five times per year. Each
pre-emergency curtailment will last no more than five hours. Customers will be
given at least 30 minutes notice before each curtailment. PG&E will request at
least six pre-emergency curtailments during any rolling three-year period. The
pre-emergency curtailments will be requested subject to the criteria listed in
Section 11.d below, and PG&E's discretion.
Annual UFR operations shall not be included in the annual pre-emergency or
emergency curtailment limit.
PRE-EMERGENCY CURT AILMENT PROCEDURE: PG&E will notify the customer
by telephone, electronic mail , or other reliable means of communication. This
notification will designate the time by which the customer s kW demand is
requested to reduce to the customer s contractual firm service level. The
notification will also designate the time when the customer may resume use of
full power.
PG&E may call a pre-emergency curtailment if one of the following criteria are
met:
1 )The 9:00 a.m. forecast of temperatures in the Central Valley (the average of
the forecasted temperature in Fresno and Sacramento) exceeds 100
degrees Fahrenheit; and PG&E has been informed by the ISO that an
adjusted 10:00 a.m. forecast of two-hour reserves for that afternoon s peak
is 12 percent or less; or
The 9:00 a.m. forecast of temperatures in the Central Valley exceeds
105 degrees F.
Advice Letter No. 2099-
Decision No. 01-04-006
Issued by
DeAnn Hapner
Vice President
Regulatory Relations
Date Filed
Effective
Resolution No.
18040-
(L)
(L)
(Continued)
Aori117.2001
ADri119.2001
44231
I &Pacific Gas and Electric Company
San Francisco, California
Cancelling
Revised
Revised
Ca/. P.C. Sheet No.
Ca/. P.C. Sheet No.
18865-
17899,
18041-
COM MER C IALII N DUSTR IAL/G E NE RAL
SCHEDULE E-19-MEDIUMGENERAL DEMAND-METEREDTIME-OF-USE SERVICE
(Continued)
11. NON-FIRM
SERVICE
PROGRAM:
(Cont'd.
EMERGENCY CURTAILMENT PROCEDURE: When it becomes necessary for
PG&E to request a curtailment, PG&E will notify the customer by telephone,
electronic mail, or other reliable means of communication. This notification will
desi9nate the time by which the customer s kW demand is requested to be
reduced to the customer s contractual firm service level.
The customer is requested to not resume the use of curtailed power until
notified by PG&E that it may do so or until the customer has curtailed its service
for six hours.
LIMIT ON EMERGENCY CURT AILMENTS: A customer will be requested to
curtail demand, under the emergency curtailment program , no more than one
time per day, four times per week , 40 hours per month, and 30 times per year.
The customer will be given at least 30 minutes notice before each curtailment.
Curtailments will not exceed six hours for any individual interruption or
100 hours for the entire year.
EMERGENCY-NOTICE PROVISION: If there is an emergency on the PG&E
system, PG&E may ask the customer to curtail the use of electricity on less
than the 30 minutes notice allowed for the Non-firm Service Option. The
customer will be asked to make its best effort to comply. The customer will not
be assessed the noncompliance penalty for failing to comply within the shorter
notice period.
The customer will be assessed a noncompliance penalty if the regular notice
period for the operation passes and the customer still has not curtailed use.
Noncompliance penalties for the period October 1,2000, to January 25,2001 , that
were held in the interruptible Load Curtailment Penalty Memorandum Account
(ILCPMA) in accordance with CPUC Decision 01-01-056 will be collected in
accordance with Decision 02-04-060. Customers will have a one-time opportunity to
elect to increase their firm service level in whole or part from November 1, 2000,
through April 30 , 2001, and pay the appropriate firm service level during this period.
For customers adjusting their firm service level during this period , penalties based
on non-compliance with the adjusted firm service level shall be collected. The
election to opt-out in part or whole will not affect the service the customer received,
and the bills due, on and after May 1 , 2001, nor does it change the customer
decision in November 2001 to have remained in or opted-out of the interruptible
program.
Curtailment events during the memorandum account period (October 1 2000
through January 25, 2001) do not count toward the tolling of compliance for
determining the level of non-compliance penalties during the subsequent year.
Advice Letter No. 2234-
Decision No. . 02-04-060
Issued by
Karen A. Tomcala
Vice President
Regulatory Relations
Date Filed
Effective
Resolution No.
(D)
(N)
(N)
(Continued)
Mav 6. 2002
May 7. 2002
46232
Pacific Gas and Electric Company
San Francisco, Galifornia
Cancelling
Revised
Revised
Cal. P.C. Sheet No.
Gal. P.u.C. Sheet No.
17900-
15328-
COMM E RCIALIINDUSTRIAL/GENE RAL
SCHEDULE E-19-MEDIUM GENERAL DEMAND-METERED TIME-OF-USE SERVICE
(Continued)
11. NON-FIRM
SERVICE
PROGRAM:
(Cont'd.
(N)
(N)
(T)
NONCOMPLIANCE PENALTY: Effective January 26, 2001, and going forward all
applicable noncompliance penalties are suspended in accordance with CPUC
Decision 01-01-056. In addition, customers will not be billed for noncompliance
penalties incurred during the period October 1 2000, to January 25, 2001.
Noncompliance penalties incurred for the period October 1 , 2000, to January 25,
2001 , will be calculated and tracked in the Interruptible Load Curtailment Penalty
Memorandum Account (ILCPMA).
Prior to October 1 , 2000, if PG&E requests that a non-firm service customer
curtail the use of electricity and the customer fails to do so by the time specified,
the customer must pay a noncompliance penalty. This penalty will be payable in
addition to the regular charges.
The penalty will be calculated by determining the total amount of excess energy
taken during the curtailment period (energy taken in excess of the customer
firm service level times the duration of the curtailment) and multiplying this total
by the noncompliance penalty (per kWh).
The applicable noncompliance penalties are listed in Section 12. If a customer
has curtailed to or below the designated firm service level for all of the requested
pre-emergency and emergency curtailments, if any, in the preceding calendar
year, the noncompliance penalty for the current year, will be the lower level
shown in Section 12.
During 1992 or until such time as PG&E calls either a pre-emergency or
emergency curtailment after June 1 , 1992, the noncompliance penalty will be the
higher noncompliance penalty shown in Section 12. No reduced noncompliance
penalties are available in 1992.
Once a customer has complied with all the requested curtailments during the
previous year , the customer s noncompliance penalty will remain at the reduced
penalty level shown in Section 12 for the next calendar year. If the customer fails
to comply with a requested curtailment, the noncompliance penalty for the
following year will be the higher value shown in Section 12.
If no emergency or pre-emergency curtailments are called during a given year
the customer s noncompliance penalty for the next year in which curtailments
occur shall be based on the customer s level of compliance during the last year
curtailments were called. New non-firm customers will be assessed the higher
noncompliance penalty during their first year on the program.
During the year, PG&E will record any energy taken in excess of the customer
firm service level during any emergency or pre-emergency curtailments. PG&E
will notify the customer of the amount of excess energy taken and the estimated
noncompliance penalty. PG&E shall assess the noncompliance penalties
subject to the noncompliance penalty limit described below, at the end of the
calendar year. The customer s noncompliance penalty shall be equal to the
appropriate noncompliance penalty shown in Section 12 times the total amount
of excess energy taken during any pre-emergency and emergency curtailments.
In any given calendar year , the noncompliance penalties may not exceed 200
percent of the annual incentive level. The noncompliance penalty limit is equal to
twice the annual incentive paid (the difference between what the customer would
have paid on firm service rates less the customer s bill on non-firm rates
excluding any noncompliance penalties). If a customer s total noncompliance
penalties in any given year exceed the noncompliance penalty limit, PG&E shall
bill the customer a noncompliance penalty equal to the noncompliance penalty
limit.
Advice Letter No. 2079-
Decision No. 01-01-056
Issued by
DeAnn Hapner
Vice President
Regulatory Relations
Date Filed
Effective
Resolution No.
(Continued)
February 5.2001
January 26. 2001
43881
I &Pacific Gas and Electric Company
San Francisco, California
Cancelling
Revised
Revised
Cal. P.C. Sheet No.
Cal. P. U. C. Sheet No.
16414-
15329-
COM M E RC IALII N DU ST R IAL/G E NE RAL
SCHEDULE E-19-MEDIUM GENERAL DEMAND-METERED TIME-OF-USE SERVICE
(Continued)
11. NON-FIRM
SERVICE
PROGRAM:
(Cont'd.
ADDITIONAL NON-FIRM SERVICE PROVISIONS:
1 )Required Re-Designations of Firm Service Level: A non-firm service
customer must maintain a difference of at least 500 kW between the firm
service level and the average monthly summer peak-period demand. If the
difference is less than 500 kW for any three summer months during any
12-month period , the customer must designate a new firm service level.
This new firm service level must be at least 500 kW below the lowest of the
customer s average peak-period demands for the I ast six summer billing
months preceding the new designation. If the customer cannot meet this
requirement, PG&E will change the account to firm service.
Optional Re-Designations of Firm Service Level: A non-firm service
customer may decrease the firm service level effective with the start of any
billing month, provided the customer gives PG&E at least 30 days' written
notice. The customer may increase the firm service level (or return to firm
service) only with PG&E's permission or by giving such notice to PG&E
during a one-month period following any revisions of the program operating
criteria initiated by the ISO, or during an annual contract review period that is
provided for between November 1 and December 1 each year. The
increased firm service level must be such that there is still at least a
500 kW difference between the firm service level and the lowest average
monthly summer peak-period demand. The increased firm service level
will become effective with the first regular reading of the meter after the
customer receives permission from PG&E or at the end of the three year
notice period. If a customer elects to change to firm service, it will not be
permitted to subsequently return to non-firm status in the future.
Telephone Line Requirements: Non-firm customers are required to make
available a telephone line and space for a notification printer. This
requirement is in addition to any other equipment requirement which may
apply.
BILL REDUCTIONS FOR NON-FIRM SERVICE CUSTOMERS:
1 )Demand Charges: Reduced peak-period demand charges for curtailable
service shall be applied to the difference between the customer s maximum
demand in the peak-period and its Firm Service Level (but not less than
zero). The peak-period charges for firm service shall be applied to the
peak-period demand less the above difference.
Energy Charges: Reduced energy charges for curtailable service shall be
applied to (a-b), where (a) is the number of kilowatt-hours used in the time
period and (b) is the product of the Firm Service Level and the number of
hours in the time period. (a-b) shall not be less than zero.
(T)
(T)
(T)
(T)
Advice Letter No.
Decision No.
1711-Issued by
Thomas E. Bottorff
Vice President
Rates Account Services
Date Filed
Effective
Resolution No.
(Continued)
November 20.1997
Aoril1.1998
40739
Pacific Gas and Electric Company
San Francisco, California
Cancelling
Revised
Revised
Cal. P.C. Sheet No.
Cal. P.C. Sheet No.
15330-
14224-
COMM ERC IAL/INDUSTRIAL/GENERAL
SCHEDULE E-19-MEDIUM GENERAL DEMAND-METERED TIME-OF-USE SERVICE
(Continued)
11. NON-FIRM
SERVICE
PROGRAM:
(Cont'd.
Advice Letter No. 1692-
Decision No. 97 -08-056
26264
PROVISIONS SPECIFIC TO UFR PROGRAM:
1 )Details on Automatic Interruptions: If a customer is participating in the
UFR program, service to the customer will be automatically interrupted if the
frequency on the PG&E system drops to 59.65 hertz for 20 cycles. PG&E
will install and maintain a digital underfrequency relay and whatever
associated equipment it believes is necessary to carry out such automatic
interruption. Relays and other equipment will remain the property of PG&E.
If more than one relay is required, PG&E will provide the additional relays
as "special facilities," at customer s expense , in accordance with Section I
of Rule 2.
In addition to the underfrequency relay, PG&E may install equipment that
would automatically interrupt service in case of voltage reductions or other
operating conditions.
Metering Requirements for UFR Program: If a customer is participating in
the UFR program under Schedule E-19 in combination with firm or
curtailable-only service , the customer will be required to have a separate
meter for the UFR service. PG&E will provide the meter sets, but the
customer will be responsible for arranging customer s wiring in such a way
that the service for each account can be provided and metered at a single
point. NOTE: Any other additional facilities required for a combination of
curtailable with firm service will be treated as "special facilities" in
accordance with Section lof Rule 2.
Communication Channel for UFR Service: UFR program customers are
required to provide an exclusive communication channel from the PG&E-
provided terminal block at the customer s facility to a PG&E-designated
control center. The communication channel must meet PG&E'
specifications, and must be provided at the customer s expense. PG&E
shall have the right to inspect the communication circuit upon reasonable
notice.
(L)
(L)
Issued by
Thomas E. Bottorff
Vice President
Rates Account Services
Date Filed
Effective
Resolution No.
(Continued)
January 28. 1998
January 1. 1998
3510
Pacific Gas and Electric Company
San Francisco, California
Original Cal. P. U.C. Sheet No.
Cal. P. U. C. Sheet No.
20512-E**
Cancelling
COM M E RC IALII N DUSTR IAL/G E NE RAl
SCHEDULE E-19-MEDIUM GENERAL DEMAND. METERED TIME-OF-USE SERVICE
(Continued)
11. NON-FIRM
SERVICE
PROGRAM:
(Conrd.
Advice Letter No. 2389-
Decision No. 03-06-032
49125
INTERACTIONS WITH OTHER DEMAND RESPONSE PROGRAMS:
Customers who participate in a third-party sponsored interruptible load
program must immediately notify PG&E of such activity.
Participants in the non-firm program may also participate in the Demand
Bidding Program (Schedule E-DBP), but will not be paid the energy
reduction incentives under the Schedule E-DBP during those hours where
a non-firm event is issued.
Participants in the non-firm program may participate in the Optional Binding
Mandatory Curtailment Program (Schedule E-OBMC) and the Pilot Optional
Binding Mandatory Curtailment Program (Schedule E-POBMC) subject to
meeting all applicable eligibility, operational and participation requirements
specified in those schedules.
Participants in the non-firm program may participate in the California Power
Authority Demand Reserves Partnership (CPA-DRP) program provided the
additional load committed to the CPA-DRP is below their Firm Service level
(FSL) under the non-firm program.
Participants on the non-firm program shall not participate in the Scheduled
Load Reduction Program (Schedule E-SLRP), or the Critical Peak Pricing
Program (Schedule E-CPP) while on the non-firm program. Participants on
the non-firm program may participate in the Base Interruptible Program
(Schedule E-BIP) only after they have completed their annual obligations
under the non-firm program.
Participants in the non-firm program may participate in the California Power
Authority Supplemental Energy Market program but will not be paid for
curtailments under the California Power Authority s program during those
hours when a non-firm event is issued.
Issued by
Karen A. Tomcala
Vice President
Regulatory Relations
Date Filed
Effective
Resolution No.
(N)
(N)
(Continued)
June 16. 2003
AuQust 1. 2003
Pacific Gas and Electric Company
San Francisco, California
Cancelling
Revised
Revised
Gal. P.G. Sheet No.
Gal. P.G. Sheet No.
20724-
20551-
COMM ERCIALIINDUSTRIAL/GENE RAL
SCHEDULE E-19-MEDIUM GENERAL DEMAND-METERED TIME-OF-USE SERVIGE
(Continued)
12. NON-FIRM
SERVICE
RATES:
These rates are applicable if the customer elects to take n on-firm service. See
Section 11 for an explanation of the non-firm service program and eligibility criteria.
Public Nuclear
Trans-Distribu-Purpose Genera-Decom-Reliability DWR Total
SECONDARY (E-19S)misSIOn lion Pr09rams tion misslonmg Services Bond Rate
Demand Charges (per kW)
Maximum Peak-Period Demand
Summer (1,52) (R)37 (I)
Winter
Maximum Part-Peak-Period Demand
Summer 16 (R)04 (I)
Winter 13 (R)02 (I)
Maximum Demand
Summer 2.41 71 (I)(2,72) (R)
Winter 2.41 71 (I)(2.72) (R)
Energy Charges (per kWh)
Peak-Period
Summer (0,00443) (R)00350 17209 (I)00036 00444 (R)17596
Winter
part-Peak-Period
Summer 00400 (R)00350 09579 (I)00036 00444 (R)10809
Winter 00453 (R)00350 10108 (I)00036 00444 (R)11391
Oll-Peak-Period
Summer 00331 (R)00350 07897 (I)00036 00444 (R)09058
Winter 00329 (R)00350 07878 (I)00036 00444 (R)09037
UFR Credit (per kWh)
(if applicable)00091 (C)-(C)00091
Noncompliance Penalty
(per kWh per event)8.40 (C)- (C)
Noncompliance Penalty
For customers who fully complied with
the previous years operations
(per kWh per event)20 (C)- (C)
Nonfirm Customer Charge
(per meter per day)11,99179 (C)- (C)11.99179
Nonfirm with UFR Customer Charge
(per meter per day)12,32033 (C)- (C)12.32033
Transmission Revenue
Balancing Account
Adjustment Rate
per kWh (0,00230)00230 00000
---------------
See Section 11 for the application of Noncompliance Penalties.The reduced Noncompliance
Penalties are not available for 1992.
Advice Letter No.
Decision No.
2424-Issued by
Karen A. Tomcala
Vice President
Regulatory Relations
Date Filed
Effective
Resolution No.
(Continued)
SeDtember 23. 2003
October 1. 2003
49218
Pacific Gas and Electric Company
San Francisco, California
Cancelling
Revised
Revised
Gal. P. U. C. Sheet No.
Gal. P.u.C. Sheet No.
20725-
20552-
COM MER C IALII N DUST R IAL/GE NE RAL
SCHEDULE E-19-MEDIUM GENERAL DEMAND-METERED TIME-OF-USE SERVICE
(Continued)
NON-FIRM
SERVICE RATES:
(Cont'd.
Public Nuclear
1rans-Distribu-Purpose Genera-Decom-Reliability DWR 10lal
PRIMARY (E-19P)mission lion Programs lion misslomng Services Bond Rate
Demand Charges (per kW)
Maximum Peak-Period Demand
Summer (3,88) (R)18 (I)
Winter
Maximum Part-Peak-Period Demand
Summer 31 (R)84 (\)
Winter 31 (R)84 (I)
Maximum Demand
Summer 2.41 06 (R)(2.07) (I)
Winter 2.41 06 (R)(2.07) (I)
Energy Charges (per kWh)
Peak-Period
Summer (0,00978) (R)00322 15407 (I)00031 00444 (R)15226
Winter
Part-Peak-Period
Summer 00077 (R)00322 08993 (\)00031 00444 (R)09867
Winter 00113 (R)00322 09789 (I)00031 00444 (R)10699
Off-Peak-Period
Summer 00070 (R)00322 07815 (I)00031 00444 (R)08682
Winter 00072 (R)00322 07912 (I)00031 00444 (R)08781
UFR Credit (per kWh)
(il applicable)00091 (C)- (C)00091
Noncompliance Penalty
(per kWh per event)8.40 (C)-(C)
Noncompliance Penalty
For customers who lully complied with
the previous year s operations
(per kWh per event)20 (C)-(C)
Nonlirm Customer Charge
(per meter per day)10.84189 (C)- (C)10,84189
Nonfirm with UFR Customer Charge
(per meter per day)11.17043 (C) -(C)11.17043
Transmission Revenue
Balancing Account
Adjustment Rate
per kWh (0.00230)00230 00000
Advice Letter No.
Decision No.
2424-Issued by
Karen A. Tomcala
Vice President
Regulatory Relations
Date Filed
Effective
Resolution No.
(Continued)
September 23. 2003
October 1 . 2003
49219
Pacific Gas and Electric Company
San Francisco, California
Cancelling
Revised
Revised
Cal. P.C. Sheet No.
Cal. P. U. C. Sheet No.
20726-
20553-
COM M E RC IALII NO USTRIAL/GE N E RAL
SCHEDULE E-19-MEDIUM GENERAL DEMAND-METERED TIME-OF-USE SERVICE
(Continued)
12.NON-FIRM SERVICE
RATES:
(Cont'd.
Public Nuclear
Trans-Distribu-Purpose Genera-Decom-Reliability DWR Total
TRANSMISSION (E.19T)mission tion Programs tion mlssloning Services Bond Rate
Demand Charges (per kW)
Maximum Peak-Period Demand
Summer (7,50) (R)50 (I)
Winter
Maximlrn Part-Peak-Period Demand
Summer (0,50) (R)60 (i)
Winter (0,50) (R)75 (I)
Maximum Demand
Summer 2.41 04 (R)(3,25) (I)
Winter 04 (R)(3.25) (I)
Energy Charges (per kWh)
Peak-Period
Summer (0,00735) (R)00326 17237 (I)00032 00444 (R)17304
Winter
Part-Peak-Period
Summer 00257 (R)00326 10520(1)00032 00444 (R)11579
Winter 00347 (R)00326 11964 (I)00032 00444 (R)13113
Off-Peak-Period
Summer 00233 (R)00326 09144 (I)00032 00444 (R)10179
Winter 00263 (R)00326 09613 (I)00032 00444 (R)10678
UFR Credit (per kWh)
(if applicable)00091 (C)-(C)00091
Noncompliance Penalty
(per kWh per event)8.40 (C)- (C)8.40
Noncompliance Penalty
For customers who fully compiied with
the previous year s operations
(per kWh per event)20 (C)- (C)
Nonfirm Customer Charge
(per meter per day)26,28337 (C)-(C)26.28337
Nonfirm with UFR Customer Charge
(per meter per day)26,61191 (C)- (C)26,61191
Transmission Revenue
Balancing Account
Adjustment Rate
per kWh (0,00230)00230 00000
Advice Letter No.
Decision No.
2424-Issued by
Karen A. Tomcala
Vice President
Regulatory Relations
Date Filed
Effective
Resolution No.
(Continued)
SeDtember 23.2003
October 1. 2003
49220
Revised Cal. P.C. Sheet No.20002-
Pacific Gas and Electric Company Cancelling Revised Cal. P.C. Sheet No.19606-
San Francisco, California
CO M MER C tALlI NO U STR IAL/G E NE RAL
SCHEDULE E-19-MEDIUM GENERAL DEMAND-METERED TIME-OF-USE SERVICE
(Continued)
12.NON-FIRM SERVICE
RATES:
(Cont'
Public Nuclear (NHN)
Trans-Distribu-Purpose Genera-Decom-Reliability DWR Total
TRANSMISSION (E-19T)missIOn tion Pr09rams tion mlssloning Services Bond Rate
Demand Charges (per kW)
Maximum Peak-Period Demand
Summer
Winter
Maximum Part-Peak-Period Demand
Summer
Winter
Maximum Demand
Summer (2.45)
Winter (2.45)
Energy Charges (per kWh)
Peak-Period
Summer 00687 00326 15746 (I)00032 00513 (N)17304 (I)
Winter
Part-Peak-Period
Summer 00521 00326 10187 (I)00032 00513 (N)11579 (I)
Winter 00643 00326 11599 (I)00032 00513 (N)13113 (I)
Off-Peak-Period
Summer 00490 00326 08818 (I)00032 00513 (N)10179 (I)
Winter 00529 00326 09278 (I)00032 00513 (N)10678(1)
UFR Credit (per kWh)
(if applicable)00091 00091
Noncompliance Penalty
(per kWh per event)8.40
Noncompliance Penalty
For customers who fully complied with
the previous year s operations
(per kWh per event)
Nonfirm Customer Charge
(per meter per day)20.04107 24230 26.28337
Nonfirm with UFR Customer Charge
(per meter per day)20.04107 57084 26.61191
Transmission Revenue
Balancing Account
Adjustment Rate
per kWh (0,00230)00230 00000
48088
Issued by
Karen A. Tomcala
Vice President
Regulatory Relations
Date Filed
Effective
Resolution No.
(Continued)
ADril1 . 2003
Aoril1. 2003Advice Letter No. 2364-
Decision No. 02-12-082
I &Pacific Gas and Electric Company
San Francisco, Galifornia
Cancelling
Revised
Revised
Gal. P.G. Sheet No.
Gal. P.C. Sheet No.
20003-
19798-
12. NON-FIRM
SERVICE
RATES:
(Cont'd.
13. COMMON-
AREA
ACCOUNTS:
14.CONTRACTS:
COM M E RC 'ALII N DUSTR IAL/GE N E RAL
SCHEDULE E-19-MEDIUM GENERAL DEMAND-METERED TIME-OF-USE SERVICE
(Continued)
Total rates include the applicable Energy Procurement Surcharges (EPS) listed in
Schedule E-EPS. Generation is calculated residually based on the total rate less the
sum of: Distribution, Transmission, Reliability Services, Public Purpose Program,
Nuclear Decommissioning, Department of Water Resources Bond ("DWR Bond"), and
FTA (where applicable).
Common-area accounts that are separately metered by PG&Eand.which took electric
service from PG&E on or prior to January 16, 2003, have a one-time opportunity to
return to a residential rate schedule from April 1 , 2004, to May 31 , 2004, by notifying
PG&E in writing.
In the event that the CPUC substantially reduces the three-cent surcharge or
substantially amends any or all of PG&E's commercial or residential rate schedules
the Executive Council of Homeowners (ECHO) can direct PG&E to begin an optional
second right-of-return period lasting 105 days. However, if this occurs prior to the
April 1 , 2004, to May 31 , 2004, time period, the ECHO directed right of return period will
be the only window for returning to a residential schedule.
Newly constructed commoncareas that are separately metered by PG&E and which
first took electric service from PG&E after January 16, 2003, have a one-time
opportunity to transfer to a residential rate schedule during a two-month window that
begins 14 months after taking service on a commercial rate schedule. This must be
done by notifying PG&E in writing. These common-area accounts have an additional
opportunity to return to a residential schedule in the event that ECHO directs PG&E to
begin a second right-of-return period.
Only those common-area accounts taking service on Schedule E-8 prior to moving to
this tariff may return to Schedule E-
Common-area accounts are those accounts that provide electric service to Common
Use Areas as defined in Rule 1.
STANDARD SERVICE AGREEMENT: To begin service under Schedule E-19 for
customers with maximum demands greater than 499 kW, the customer shall be
required to sign PG&E's Electric General Service Agreement (GSA). The GSA
has an initial term of three (3) years , once the three-year initial term is over, the
agreement will automatically continue in effect for successive terms of one year
each until it is cancelled. Customers may, at any time, request PG&E to modify
the GSA if the service arrangements, electrical demand requirements, or delivery
criteria to its premises change. However, customers will still be obligated to
perform the terms and conditions outlined in any other agreements that
supplement the GSA.
Customer load shall only be served under only one of PG&E's discount
agreements. These agreements include, but are not limited to, PG&E's non-firm
service agreement and the long-term service options described below.
Customers requesting service under any of these discount agreements shall be
required to sign a supplemental agreement to the GSA.
LONG-TERM SERVICE AGREEMENT OPTIONS: Certain customers who would
prefer to contract with PG&E for the supply and delivery of electricity into the future
may qualify for a long-term service agreement with PG&E. These agreements
will supplement and be made part of the GSA. Long-term service agreements
are intended to attract or retain efficient electric load to PG&E's service territory,
and were approved in Decision 95-10-033.
(T)
(T)
Advice Letter No. 2364-
Decision No. 02-12-082
Issued by
Karen A. Tomcala
Vice President
Regulatory Relations
Date Filed
Effective
Resolution No.
(Continued)
Aoril1. 2003
Aoril1. 2003
48089
1 &
Pacific Gas and Electric Company
San Francisco, California
Cancelling
Revised
Revised
Cal. P.C. Sheet No.
Cal. P.C. Sheet No.
20004-
19799-
COM MER C IALII N DUSTRIALIG EN E RAL
SCHEDULE E-19-MEDIUM GENERAL DEMAND-METEREDTIME-OF-USE SERVICE
(Continued)
14. CONTRACTS:
(Cont'd.
LONG-TERM SERVICE AGREEMENT OPTIONS: (Cont'd.
PG&E shall not be permitted to enter into any long-term service agreements after
June 1 , 1999 , or after elimination of the Electric Revenue Adjustment Mechanism
(ERAM) and/or the effective date of a decision establishing Performance Base
Ratemaking for the electric operations of PG&E, whichever occurs first. Any
long-term service agreements entered into by PG&E prior to the end of eligibility
for these contracts will be carried out to their completion dates or termination,
whichever occurs first.
Customers may qualify for one of two long-term agreements:
Agreement for Attracting Manufacturing Business and Electric Load
Agreement for the Expansion and Retention of Incrementa I Electric Load
A general description of these agreements is given below. Specific terms and
conditions for these long-term agreements, as well as their associated rate
discounts , are detailed in the respective CPUC-approved standard form
agreement, or as otherwise provided for in Decision 95-10-033.
BUSINESS ATTRACTION AGREEMENT: This agreement is intended solely
for customers with maximum demands greater than 499 kW who are
locating or permanently expanding their plant facilities and electrical load
within PG&E's service territory. This agreement provides those customers
with a declining discount to be applied to PG&E's applicable bundled rate
as well as a service connection incentive.
To qualify for this agreement, a customer must: (1) add at least
380 000 kWh/year of new load to PG&E's system, (2) have a designated
activity SIC code between 2000-3999 or not be constrained to locate within
PG&E's service territory, and (3) sign an affidavit stating that the availability
of this agreement is a material factor in its decision to add this load within
PG&E's service territory. Qualification under the material factor criterion will
require in part that customer s monthly electric costs exceeding, on
average, five percent (5%) of its facility s variable operating costs, unless
this agreement is to be part of a larger state and local government package
to attract its business to California.
Qualifying customers may sign a six- (6) or ten- (10) year agreement. The
declining discount percentages applied to the customer s applicable rate
schedule will be 20%, 15%, 10% for the six-year agreement, or 20%, 15%,
15%, 10%, 10% for the ten-year agreement, both applied to the total bill as
calculated for Bundled Service Customers less the EPS revenues
calculated using the rates provided in Schedule E-EPS. These discounts
will be applied over the first three and five years, respectively, of the
agreement's term. As an alternative, a customized discount schedule with
a net present value equivalent to the declining discount streams listed
above may be developed by the customer. The availability of the Business
Attraction Agreement is subject to a maximum participation limit of 100 MW
including participation on all PG&E rate schedules.
Advice Letter No. 2364-
Decision No. 02-12-082
Issued by
Karen A. Tomcala
Vice President
Regulatory Relations
Date Filed
Effective
Resolution No.
(T)
(T)
(Continued)
ADri11. 2003
ADril1 . 2003
48090
I &Pacific Gas and Electric Company
San Francisco, California
Cancelling
Revised
Revised
Cal. P.C. Sheet No.
Cal. P. U. C. Sheet No.
19800-
16418-
COMM E RC IALIINDUSTRIAL/GENERAL
SCHEDULE E-19-MEDIUM GENERAL DEMAND-METERED TIME-OF-USE SERVICE
(Continued)
14. CONTRACTS:
(Cont'd.
LONG-TERM SERVICE AGREEMENT OPTIONS: (Cont'd.(T)
BUSINESS EXPANSION AND RETENTION AGREEMENT: This agreement
is intended to attract incremental load or retain existing load that would,
without this agreement, not be able to locate or remain in PG&E's service
territory. This agreement is available to PG&E customers with maximum
demands greater than 499 kW who are choosing between an incremental
expansion or retention of their manufacturing plant in PG&E's service
territory and a comparable, "similarly situated plant" outside of PG&E'
service territory. PG&E's capital investment to accommodate the
customer s new load under this agreement must be less than twenty-five
thousand dollars ($25,000).
To be eligible for this option, a customer must: (1) add or retain at least
380,000 kWh/year of eligible load to PG&E's system, (2) have a
designated activity SIC code between 2000-3999 or not be constrained to
locate within PG&E's service territory, (3) have a similarly situated site that
is competing for the load , and (4) sign an affidavit testifying that the
availability of this agreement is a material factor in the decision to expand or
retain this load at its manufacturing plant in PG&E's service territory.
Qualification under the material factor criterion will require, in part, that
customer s monthly electric costs exceed, on average, five percent (5%) of
its facility s variable operating costs, unless this agreement is to be part of
a larger state and local government package to attract its business to
California. The availability of the Business Expansion and Retention
Agreement is subject to a maximum participation limit of 50 MW, including
participation on all PG&E rate schedules.
Qualifying customers may sign a three- (3) or five- (5) year agreement. The
initial rate for the customer s eligible load will be equal to the average
comparable utility rate in the geographical area where the similarly situated
plant is located. The initial rate will be escalated annually by the percent
increase , or decrease, of the competing area s average utility rate.
Discounted rates will be subject to a Discount Floor price, as defined in
Decision 95-10-033.
In order to qualify for any of these long-term agreements:
1 )Customer annual usage will be determined using PG&E's billing data from
the twelve (12) months immediately preceding the date the customer
requests to be considered for service under one of these agreements, if
that data is not available or if the customer s operation is expected to
significantly change within the next year, PG&E's estimate of the customer
upcoming twelve (12) months of usage;
47821
Issued by
Karen A. Tomcala
Vice President
Regulatory Relations
Date Filed
Effective
Resolution No.
(Continued)
Februarv 14. 2003
Januarv 16. 2003Advice Letter No. 2344-
Decision No. 03-01-037
I &Pacific Gas and Electric Company
San Francisco, California
Cancelling
Revised
Original
Cal. P.C. Sheet No.
Cal. P.C. Sheet No.
19801-
16419-
COMM E RCIAL/IN DUSTRIAL/GENERAL
SCHEDULE E-19-MEDIUM GENERAL DEMAND-METERED TIME-OF-USE SERVICE
(Continued)
14. CONTRACTS:
(Cont'd)
Advice Letter No. 2344-
Decision No. 03-01-037
47822
LONG-TERM SERVICE AGREEMENT OPTIONS: (Cont'd.(T)
New load" is defined as load that has not been served on a regular or
continuous basis from PG&E distribution , transmission or generation
facilities during the twelve (12) months immediately preceding the date the
customer requests;
PG&E shall determine whether or not the discount under these agreements
is a material factor in the customer s decision to locate, retain, or expand its
load within PG&E's service territory. However, a customer may contest
PG&E's determination by filing a complaint with the CPUC; and
A customer may be required to provide business operation information that
is relevant to establishing its initial rate level , or verifying its subsequent
rate level. The customershall be responsible for demonstrating, to PG&E'
satisfaction, the credibility of all business operation information relevant to
establishing or verifying its rate level as it applies to its premise.
Information requirements, if any, are outlined in the long term agreements.
However, if a customer disagrees with PG&E's conclusion regarding the
credibility of any information provided by the customer, the customer may
contest PG&E's determining by filing a complaint at the CPUC.
If a customer has multiple electrical accounts located on a single premise,
PG&E may, at its discretion, aggregate those accounts for the sole purpose
of qualifying for these agreements. Aggregated account information shall
not be used to create a conjunctively derived bill for the customer s premise.
PG&E may, at is sole discretion , disqualify a customer from participating in
anyone of these long-term options if (1) PG&E believes that the costs to
provide adequate transmission and distribution facilities make discounting
to a particular customer uneconomic (that is, the customer specific
marginal costs exceeds the price for the otherwise applicable schedule), or
(2) a customer severely constrains the existing transmission and
distribution system in such a way that that customer s marginal costs in the
future are expected to be above the price that would otherwise result from
the long-term contract option.
All long-term agreement rate discounts apply only to a qualifying customer
eligible load. Therefore , a qualifying customer may have an electric rate discount
applied to all or only a portion of its usage at its premise. For the Business
Attraction and the Business Expansion and Retention Agreements, discounts
will be applied only to electric usage in excess of the customer s prescribed
Base level" amount. The Base Level shall be equal to PG&E's estimate of the
average annual usage at the customer s premise if a long-term agreement was
not executed.
Issued by
Karen A. Tomcala
Vice President
Regulatory Relations
Date Filed
Effective
Resolution No.
(Continued)
February 14. 2003
January 16. 2003
1 &Pacific Gas and Electric Company
San Francisco, California
Cancelling
Revised
Revised
Ca/. P.C. Sheet No.
Ca/. P.C. Sheet No.
20727 -
19802-
COM MER C tALIIN DUSTR IALIG ENE RAL
SCHEDULE E-19-MEDIUM GENERAL DEMAND-METERED TIME-OF-USE SERVICE
(Continued)
14. CONTRACTS:
(Cont'd.
LONG-TERM SERVICE AGREEMENT OPTIONS: (Cont'd.
My portion of the customer s load that does not qualify for service under these
agreements will be served under this rate schedule.
15. VOLUNTARY
SERVICE
PROVISIONS:
All applicable rates, rules, and tariffs shall be remain in force for those
customers who sign a long-term agreement. In the event of a conflict, the
terms provided within the long term agreement shall supersede those set forth
in the standard CPUC-approved tariffs.
Customers voluntarily taking service on Schedule E-19 (see Applicability Section)
shall be governed by all the terms and conditions shown in Sections 1 through 13,
unless different terms and conditions are shown below.
DEFINITION OF MAXIMUM DEMAND: Demand will be averaged over 15-minute
intervals except, in special cases. "Maximum demand" will be the highest of all
15-minute averages for the billing month.
SPECIAL CASES: (1) If the customer s maximum demand has exceeded
400 kW for three consecutive months, 30-minute intervals will be used for
averaging. The customer will be returned to 15-minute intervals when its
maximum demand has dropped below 300 kW and remains there for
12 consecutive months. (2) If the customer s use of energy is intermittent or
subject to violent fluctuations, a 5-minute or 15-minute interval may be used.
(3) If the customer uses welders, the demand charge will be subject to the
minimum demand charges for those welders' ratings, as explained in
Section J of Rule 2.
REDUCED CUSTOMER CHARGE: The reduced customer charge will be
assessed only if the customer is taking service under this schedule on a
voluntary basis or if the customer s maximum billing demand has not exceeded
499 kW for 12 or more consecutive months.
SERVICE CONTRACTS: This rate schedule will remain in effect for at least
twelve consecutive months before another schedule change is made, unless
the customer s maximum demand has exceeded 499 kW for three consecutive
months.
16. BILLING:A customer s bill is calculated based on the option applicable to the customer.(T)
Advice Letter No.
Decision No.
2424-Issued by
Karen A. Tomca/a
Vice President
Regulatory Relations
Date Filed
Effective
Resolution No.
(Continued)
September 23. 2003
October 1. 2003
49221
~ I &Pacific Gas and Electric Company
San Francisco, California
Cancelling
Revised
Revised
Gal. P.C. Sheet No.
Gal. P. U. C. Sheet No.
20728-
20005-
16. BILLING:
17. RATE
REDUCTION
BOND
CREDIT:
18. CARE
DISCOUNT
FOR
NONPROFIT
GROUP-
LIVING AND
SPECIAL
EMPLOYEE
HOUSING
FACILITIES:
Advice Letter No.
Decision No.
49222
COM M E RCIAl/I N DUSTRIALIG ENE RAL
SCHEDULE E-19-MEDIUM GENERAL DEMAND-METERED TIME-OF-USE SERVICE
(Continued)
Bundled Service Customers receive supply and delivery services solely from PG&E.
The customer s bill is based on the Total Rates and Conditions set forth in this
schedule, which includes the EPS as provided in Schedule E-EPS (where applicable).
Direct Access Customers purchase energy from an energy service provider and
continue receiving delivery services from PG&E. Direct Access bills are equal to the
sum of charges for transmission, reliability services, distribution, public purpose
programs, nuclear decommissioning, the FT A (where applicable), the franchise fee
surcharge, and the Direct Access Cost Responsibility Surcharge (DA CRS). The DA
CRS is equal to the sum of the individual charges set forth below. Exemptions to the
DA CRS are set forth in Schedule DA CRS.
DWR Power Charge (per kWh) $0.02256
DWR Bond Charge (per kWh) $0.00444
Total DA CRS (per kWh)$0.02700
Hourly Pricing Option: This option is suspended.
Small commercial customers with loads less than 20 kW shall receive a 10 percent
credit by way of a reduction to generation based on the total bill as calculated for
Bundled Service Customers less the EPS revenue as provided in Schedule E-EPS.
Only customers determined as eligible will receive the credit.
Additionally, customers eligible for the credit are obligated to pay a Fixed Transition
Amount (FT A), also referred to as a Trust Transfer Amount (TT A), as described in
Schedule E-RRB and defined in Preliminary Statement Part AS.
Facilities which meet the eligibility criteria in Rule 19.2 or 19.3 are eligible for a
California Alternate Rates for Energy discount under Schedule E-CARE.
All customers served on this Schedule shall pay the DWR Bond charge, except those
customers who are eligible for CARE. For CARE customers, no portion of the rates
shall be used to pay the DWR Bond charge. Generation is calculated residually based
on the total rate less the sum of the following: Transmission, Reliability Services
Distribution , Public Purpose Programs, Nuclear Decommissioning, and FTA (where
applicable).
(T)
(T)
(D)
(D)
(T)
2424-Issued by
Karen A. Tomcala
Vice President
Regulatory Relations
Date Filed
Effective
Resolution No.
(Continued)
Seotember 23. 2003
October 1. 2003
I &Pacific Gas and Electric Company
San Francisco, California
Cancelling
Revised
Revised
Gal. P. U. C. Sheet No.
Gal. P. U. C. Sheet No.
19805-
17095-
COM MER C IALII N 0 U STR IAL/G E NE RAL
SCHEDULE E-19-MEDIUM GENERAL DEMAND-METERED TIME-OF-USE SERVICE
(Continued)
19. OPTIONAL
OPTIMAL
BilLING
PERIOD
SERVICE:
(Cont'd.
Eliqibilitv (Cont'd.(1)
The customer would retain the protection of the summer average rate limiter in
all summer months including the revised subject and adjacent months, where
the rate limiter is imposed before the additional customer charge in Section
20.c has been included in the bill calculation.
To qualify, the duration of the customer s high seasonal production period
must be six (6) months or less, and the customer s energy consumption
during its high seasonal production cycle must be at least 2.0 times its
consumption during its low seasonal production cycle for the most recent
twelve (12) month period. Customers that discontinue this option may not
enroll in this option again for a period of twelve (12) months. The customer
must also specify which six (6) consecutive calendar months will be the
optimal billing period. The optimal billing period must encompass the
customer s high seasonal production period.
Customer Notification to PG&E
Upon enrollment, the customer shall notify PG&E of the approximate two
months where seasonal production starts and ends. As they occur, the
customer shall notify PG&E of the exact seasonal production start and end
dates. Upon notification by the customer of a production start date during a
summer month, PG&E will wait until the regular read date to verify that the
regular subject month bill would have otherwise invoked the rate limiter. If the
rate limiter is invoked for the summer subject start month, the customer will be
billed based on the optimal meter read dates or the regular scheduled meter
read dates, whichever is the lower bill. Throughout the six month period,
customers will receive their regular bill. Approximately two months after the
production start or end date , the customer will receive a credit, if one should
apply, for the optimal billing period. If a credit does not apply, the customer will
not receive additional billing. If the rate limiter does not otherwise apply, the
regular subject month bill based on the old read date will be issued, and the
customer can then request the special optimal bill option in only one
production end date "subject" month. The application of this billing option to a
production end date may occur prior to its application to a production start
date, such as when a customer has more than one high production cycle. The
customer must notify PG&E in writing, via facsimile (fax) to both the PG&E
account representative and PG&E's Customer Billing Department, of the
production start or end date within two days of the production start or end date.
Customers will receive from PG&E's Customer Billing Department a fax
receipt verification upon notice of a production start or end date. PG&E will
notify the customer of the regularly scheduled meter read dates and, upon
request, the customer s rate limiter history.
47826
Issued by
Karen A. Tomca/a
Vice President
Regulatory Relations
Date Filed
Effective
Resolution No.
(Conti nued)
February 14. 2003
January 16. 2003Advice Letter No. 2344-
Decision No. 03-01-037
Pacific Gas and Electric Company
San Francisco, California
Cancelling
Revised
Revised
Cal. P.u.C. Sheet No.
Cat. P.C. Sheet No.
20730-
19806-
19.0PTIONAL
OPTIMAL
BILLING
PERIOD
SERVICE:
(Cont'
20. ELECTRIC
EMERGENCY
PLAN
ROTATING
BLOCK
OUTAGES
Advice Letter No.
Decision No.
49224
COM MER C IALII N DUSTR IAL/GE N E RAL
SCHEDULE E-19 MEDIUM GENERAL DEMAND-METERED TIME-OF-USE SERVICE
(Continued)
Customer CharGe
Upon enrollment, a special customer charge will be assessed in all six
(6) months in the optimal billing period to cover the incremental costs of the
required solid state recorder, special program billing, recruitment, and
administrative costs. The customer charge shall be $130 per meter per optimal
billing period month for primary and secondary voltage customers. The
customer is obligated to pay this monthly customer charge only while enrolled in
this option but any customer that drops out may not enroll in this option again for
a period of twelve (12) months. Customers who have signed contracts and are
awaiting solid state recorders so that they can participate in the program will not
be assessed the special customer charge until a solid state recorder has been
installed.
For billing purposes, the special customer charge for the optimal billing period
service shall be assigned to Distribution.
Proration of CharGes
All applicable customer charges, demand charges or other applicable fixed
charges, shall be prorated as specified in Rule 9. As specified in Rule 9,
Sections A and B , the regular billing period will be once each month, and
prorations for monthly bills of less than 27 or more than 33 days shall be
calculated on the basis of the number of days in the period in question to the
total number of days in an average month , as specified in Rule 9.
Functional AssiGnment of Credit
For billing purposes, the Optimal Billing Credit will be assigned to Distribution.
(T)
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 rotating outage group so that the customer does not escape
curtailment. If the transmission level customer fails to cooperate and drop load at
PG&E's request, automatic equipment controlled by PG&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 PG&E, but approval may not be unreasonably withheld.
2424-Issued by
Karen A. Tomca/a
Vice President
Regulatory Relations
Date Filed
Effective
Resolution No.
(Continued)
September 23. 2003
October 1 . 2003
I &Pacific Gas and Electric Company
San Francisco, California
Cancelling
Revised
Original
Cal. P. U. C. Sheet No.
Cal. P.C. Sheet No.
20731-
20006-
20. STANDBY
APPLICA-
BILITY:
21. DWR BOND
CHARGE:
CO M M E RC IALII N DUST R IALIGE N E RAL
SCHEDULE E-19-MEDIUM GENERAL DEMAND-METERED TIME-OF-USE SERVICE
(Continued)
DISTRIBUTED ENERGY RESOURCES EXEMPTION: Customers qualifying for an
exemption from standby charges under Public Utilities (PU) Code Sections 353.1 and
353.3, as described above, must take service on a time-of-use (TOU) schedule in
order to receive this exemption until a real-time pricing program, as described in PU
Code 353.3, is made available. Once available, customers qualifying for the standby
charge exemption must participate in the real-time program referred to above.
Qualification for and receipt of this distributed energy resources exemption does not
exempt the customer from metering charges applicable to time-of-use (TOU) and real-
time pricing, or exempt the customer from reasonable interconnection charges, non-
bypassable charges as required in Preliminary Statement BB - Competition Transition
Charge Responsibility for All Customers and CTC Procurement or obligations
determined by the Commission to result from participation in the purchase of power
through the California Department of Water Resources, as provided in PU Code
Section 353.
The Department of Water Resources (DWR) Bond Charge was imposed by California
Public Utilities Commission Decision 02-10-063, as modified by Decision 02-12-082,
and is property of DWR for all purposes under California law. The Bond Charge
applies to all retail sales, excluding CARE and Medical Baseline sales. The DWR
Bond Charge (where applicable) is included in customers' total billed amounts.
Generation charges are reduced such that total charges do not increase as a result of
the initial imposition of the bond charge.
(T)
Advice Letter No.
Decision No.
2424-Issued by
Karen A. Tomcala
Vice President
Regulatory Relations
Date Filed
Effective
Resolution No.
September 23. 2003
October 1, 2003
49225