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RATES
PRR | CVP Rates | PACI Rates | COTP Rates | Past Rates | Past Restoration Fund Info



CVP Rate Review Process (Ongoing)
Federal Register Notices - CVP, COTP and PACI
Washoe Project (Stampede) 2008 Rate Case Public Process
Restoration Fund
Other Issues
Power Revenue Requirement
Transmission Rates

Western's Rates Public Process Procedures

CURRENT YEAR RATES

FY 2012 Revenue Requirements and Rates
October 2011 through September 2012
 
All Rates include 3 components. The rates and revenue requirements listed in this table are for Component 1 only. For information on components 2 and 3, see the note at the bottom of the table.


POWER

FY 2012 Revenue Requirement/Rates

Applicable
Rate Schedule

 

Oct 11 - Sep 12

 

 

 

$ 73,344,401

CV-F13

First Preference Customers' Percentages:
(apply to the Power Revenue Requirement)

 

Oct 11 – Sep 12

Sierra CC

0.28%

Calaveras PPA

0.71%

Trinity PUD

2.33%

Tuolumne PPA

0.53%

Total

3.85%

First Preference Revenue Requirement

$2,823,759

CV-F13

Base Resource Revenue Requirement

Oct 11 – Mar 12 Monthly
Apr 12 – Sep 12 Monthly

$70,520,642

$2,938,360
$8,815,080

CV-F13

Custom Product Power

Pass-through of all costs

CPP-2

CVP TRANSMISSION

Rates effective Oct 1, 11 - Mar 31, 12

Rates effective April 1, 11 - Sep 30, 11

Applicable
Rate Schedule

CVP Transmission Rate - monthly ($/kW-Month)

$ 1.23

$1.04

CV-T3 / T2

CVP Transmission Rate - hourly (mills/kWh)

1.69

1.43

CV-T3 / T2

CVP Transmission Rate - daily (mills/kW-day)

40.44

34.20

CV-T3 / T2

CVP Network Integration Transmission Service
(NITS) Revenue Requirement ($/month)

$ 2,239,921

$1,783,441

CV-NWT5 / NWT4

PACI TRANSMISSION -- Spring Rate for April 2011 – May 2011

Rates

Applicable
Rate Schedule

PACI Pt-to-Pt (mills/kW-Day)

29.08

PACI-T2

PACI Pt-to-Pt ($/kW-Day)

$ 0.0291

 

PACI Pt-to-Pt ($/MW-Day)

$ 29.08

 

PACI Pt-to-Pt ($/MW-Month)

$ 887.00

 

PACI Pt-to-Pt ($/MWh)

$ 1.21

 

PACI TRANSMISSION -- Summer Rate for October 1, 2011 – October 31, 2011

Rates

Applicable
Rate Schedule

PACI Pt-to-Pt (mills/kW-Day)

28.84

PACI-T3

PACI Pt-to-Pt ($/kW-Day)

$ 0.0288

 

PACI Pt-to-Pt ($/MW-Day)

$ 28.84

 

PACI Pt-to-Pt ($/MW-Month)

$ 871.00

 

PACI Pt-to-Pt ($/MWh)

$ 1.20

 

PACI TRANSMISSION -- Winter Rate for November 1, 2011 – March 31, 2012

Rates

Applicable
Rate Schedule

PACI Pt-to-Pt (mills/kW-Day)

28.84

PACI-T3

PACI Pt-to-Pt ($/kW-Day)

$0.0288

 

PACI Pt-to-Pt ($/MW-Day)

$28.84

 

PACI Pt-to-Pt ($/MW-Month)

$871.00

 

PACI Pt-to-Pt ($/MWh)

$1.20

 

COTP TRANSMISSION – Spring Rate for April 2011 - May 2011

Rates

Applicable
Rate Schedule

COTP Pt-to-Pt (mills/kW-Day)

66.20

COTP-T2

COTP Pt-to-Pt ($/kW-Day)

$ 0.0662

 

COTP Pt-to-Pt ($/MW-Day)

$ 66.20

 

COTP Pt-to-Pt ($/MW-Month)

$ 2,019.00

 

COTP Pt-to-Pt ($/MWh)

$ 2.76

 

COTP TRANSMISSION – Summer Rate for October 1, 2011 - October 31, 2011

Rates

Applicable
Rate Schedule

COTP Pt-to-Pt (mills/kW-Day)

64.97

COTP-T3

COTP Pt-to-Pt ($/kW-Day)

$ 0.0650

 

COTP Pt-to-Pt ($/MW-Day)

$ 64.97

 

COTP Pt-to-Pt ($/MW-Month)

$ 1,962

 

COTP Pt-to-Pt ($/MWh)

$ 2.71

 

COTP TRANSMISSION – Winter Rate for November 1,2011 – March 31, 2012

Rates

Applicable
Rate Schedule

COTP Pt-to-Pt (mills/kW-Day)

64.97

COTP-T3

COTP Pt-to-Pt ($/kW-Day)

$0.0650

 

COTP Pt-to-Pt ($/MW-Day)

$64.97

 

COTP Pt-to-Pt ($/MW-Month)

$1,962.00

 

COTP Pt-to-Pt ($/MWh)

$2.71

 

TRANSMISSION OF WESTERN POWER BY OTHERS

Applicable
Rate Schedule

Pass-through of all costs

CV-TPT7

UNRESERVED USE PENALTIES

Applicable
Rate Schedule

A transmission customer that has not reserved capacity or exceeds its firm or non-firm reserved capacity at any point of receipt or any point of delivery will be assessed Unreserved Use Penalties. The penalty charge for a transmission customer who engages in unreserved use is 200 percent of Western's approved transmission service rate for PTP transmission service.

CV-UUP1

ANCILLARY SERVICES

Rates effective Oct 1, 11 - Mar 31, 12

Rates effective Apr 1, 11 - Sept 30, 11

Applicable
Rate Schedule

Regulation and Frequency Response ($/kW-month)

$3.91

$4.33

CV-RFS4 / RFS3

Spinning Reserve

The formula rate for spinning reserve service is the price consistent with the California Independent System Operator's market plus all costs incurred as a result of the sale of spinning reserves, such as Western's scheduling costs. For customers that have a contractual obligation to provide spinning reserve to Western and do not fulfill that obligation, the penalty for non-performance is the greater of 150 percent of Western's actual cost or 150 percent of the market price.

CV-SPR4

Supplemental Reserve

The formula rate for supplemental reserve service is the price consistent with the California Independent System Operator's market plus all costs incurred as a result of the sale of supplemental reserves, such as Western's scheduling costs. For customers that have a contractual obligation to provide supplemental reserve service to Western and do not fulfill that obligation, the penalty for non-performance is the greater of 150 percent of Western's actual cost or 150 percent of the market price.

CV-SUR4

Energy Imbalance

Energy Imbalance service is applied to deviations as follows: (1) for deviations within the bandwidth, there will be no financial settlement, unless otherwise dictated by contract or policy; rather, EI will be tracked and settled with energy; (2) negative deviations (under-delivery), outside the deviation bandwidth, will be charged the greater of 150 percent of the California Independent System Operator market price or 150 percent of Western's actual cost; and (3) positive deviations (over-delivery), outside the deviation bandwidth, will be lost to the system, except for any hour when Western incurs a cost to dispose of the energy, then that cost will be borne by the responsible party.

CV-EID4

Generator Imbalance

Generator Imbalance service is applied to deviations as follows: (1) for deviations within the bandwidth, there will be no financial settlement, unless otherwise dictated by contract or policy; rather, GI will be tracked and settled with energy; (2) negative deviations (under-delivery), outside the deviation bandwidth, will be charged the greater of 150 percent of the California Independent System Operator market price or 150 percent of Western's actual cost; and (3) positive deviations (over-delivery), outside the deviation bandwidth, will be lost to the system, except for any hour when Western incurs a cost to dispose of the energy, then that cost will be borne by the responsible party.

CV-GID1

Component 2:
Any charges or credits associated with the creation, termination, or modification to any tariff, contract, or rate schedule accepted or approved by the Federal Energy Regulatory Commission (FERC) or other regulatory bodies will be passed on to each relevant customer. The FERC's or other regulatory bodies' accepted or approved charges or credits apply to the service to which this rate methodology applies.
When possible, Western will pass through directly to the relevant customer FERC's or other regulatory bodies' accepted or approved charges or credits in the same manner Western is charged or credited. If FERC's or other regulatory bodies' accepted or approved charges or credits cannot be passed through directly to the relevant customer in the same manner Western is charged or credited, the charges or credits will be passed through using Component 1 of the formula rate.

Component 3:
Any charges or credits from the Host Balancing Authority (HBA) applied to Western for providing this service will be passed through directly to the relevant customer in the same manner Western is charged or credited to the extent possible. If the HBA's costs or credits cannot be passed through to the relevant customer in the same manner Western is charged or credited, the charges or credits will be passed through using Component 1 of the formula rate.