RATES

FY 2010 Revenue Requirements and Rates
October 2009 through September 2010

All Rates (except Custom Product Power) 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 2010 Revenue Requirement/Rates

Applicable
Rate Schedule

Oct 09 - Sep 10

$77,609,919

CV-F12

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

	Oct 09 – Sep 10
Sierra CC	0.50%
Calaveras PPA	1.10%
Trinity PUD	3.48%
Tuolumne PPA	0.94%
Total	6.02%

First Preference Revenue Requirement

$4,672,117

CV-F12

Base Resource Revenue Requirement

Oct 09 – Mar 10 Monthly
Apr 10 – Sep 10 Monthly

$72,937,802

$3,039,075
$9,117,225

CV-F12

Custom Product Power

Pass-through of all costs

CPP-1

CVP TRANSMISSION	Rates effective Oct 1, 09 - Mar 31, 10	Applicable Rate Schedule
CVP Transmission Rate - monthly ($/kW-Month)	$ 1.00	CV-T2
CVP Transmission Rate - hourly (mills/kWh)	1.37	CV-T2
CVP Transmission Rate - daily (mills/kW-day)	32.88	CV-T2
CVP Network Integrated Transmission Service (NITS) Revenue Requirement ($/month)	$ 1,751,086	CV-NWT4

PACI TRANSMISSION -- Spring Rate for April 2009 – May 2009	Rates	Applicable Rate Schedule
PACI Pt-to-Pt (mills/kW-Day)	27.54	PACI-T2
PACI Pt-to-Pt ($/kW-Day)	$ 0.0275
PACI Pt-to-Pt ($/MW-Day)	$ 27.54
PACI Pt-to-Pt ($/MW-Month)	$ 840.00
PACI Pt-to-Pt ($/MWh)	$ 1.15

PACI TRANSMISSION -- Summer Rate for June 2009 – October 2009	Rates	Applicable Rate Schedule
PACI Pt-to-Pt (mills/kW-Day)	27.45	PACI-T2
PACI Pt-to-Pt ($/kW-Day)	$ 0.0275
PACI Pt-to-Pt ($/MW-Day)	$ 27.45
PACI Pt-to-Pt ($/MW-Month)	$ 840.00
PACI Pt-to-Pt ($/MWh)	$ 1.14

PACI TRANSMISSION -- Winter Rate for November 2009 – March 2010	Current Rates	Applicable Rate Schedule
PACI Pt-to-Pt (mills/kW-Day)	32.68	PACI-T2
PACI Pt-to-Pt ($/kW-Day)	$ 0.0327
PACI Pt-to-Pt ($/MW-Day)	$32.68
PACI Pt-to-Pt ($/MW-Month)	$987.00
PACI Pt-to-Pt ($/MWh)	$1.36

COTP TRANSMISSION – Spring Rate for April 2009 - May 2009	Rates	Applicable Rate Schedule
COTP Pt-to-Pt (mills/kW-Day)	64.59	COTP-T2
COTP Pt-to-Pt ($/kW-Day)	$ 0.06459
COTP Pt-to-Pt ($/MW-Day)	$ 64.59
COTP Pt-to-Pt ($/MW-Month)	$ 1,970.00
COTP Pt-to-Pt ($/MWh)	$ 2.69

COTP TRANSMISSION – Summer Rate for June 2009 - October 2009	Rates	Applicable Rate Schedule
COTP Pt-to-Pt (mills/kW-Day)	68.76	COTP-T2
COTP Pt-to-Pt ($/kW-Day)	$ 0.06876
COTP Pt-to-Pt ($/MW-Day)	$ 68.76
COTP Pt-to-Pt ($/MW-Month)	$ 2,104.00
COTP Pt-to-Pt ($/MWh)	$ 2.86

COTP TRANSMISSION – Winter Rate for November 2009 – March 2010	Current Rates	Applicable Rate Schedule
COTP Pt-to-Pt (mills/kW-Day)	86.13	COTP-T2
COTP Pt-to-Pt ($/kW-Day)	$0.0861
COTP Pt-to-Pt ($/MW-Day)	$86.13
COTP Pt-to-Pt ($/MW-Month)	$2,601.00
COTP Pt-to-Pt ($/MWh)	$3.59

TRANSMISSION OF WESTERN POWER BY OTHERS	Applicable Rate Schedule
Pass-through of all costs	CV-TPT6

ANCILLARY SERVICES	Rates effective Oct 1, 09 - Mar 31, 10	Rates effective Apr 1, 09 - Sept 30, 09	Applicable Rate Schedule
Regulation and Frequency Response ($/kW-month)	$5.17	$4.21	CV-RFS3
Spinning Reserve	Prices consistent with CAISO market plus all costs incurred due to the sale of spinning reserves. The penalty for customers that do not fulfill their contractual obligation to provide reserves is the greater of actual costs or 150% of market price.		CVSPR3
Non-Spinning Reserve	Prices consistent with CAISO market plus all costs incurred due to the sale of non-spinning reserves. The penalty for customers that do not fulfill their contractual obligation to provide reserves is the greater of actual costs or 150% of market price.		CV-SUR3
Energy Imbalance	The charge for hourly average negative deviation (under delivery) outside the bandwidth is the greater of 150 percent of market price or actual cost. Hourly average positive deviation outside the bandwidth is lost to the system.		CV-EID3

Component 2:
Any charges or credits associated with the creation, termination, or modification to any tariff, contract, or schedule accepted or approved by the Federal Energy Regulatory Commission (Commission) or other regulatory body will be passed on to each appropriate Customer. The Commission or other regulatory body 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 appropriate Customer, the Commission or other regulatory body accepted or approved charges or credits in the same manner Western is charged or credited. If the Commission or other regulatory body accepted or approved charges or credits cannot be passed through directly to the appropriate Customer, the charges or credits will be passed through using Component 1 of the formula rate.
Component 3:
Any charges or credits from the Host Control Area (HCA) applied to Western for providing this service will be passed through directly to the appropriate Customer in the same manner Western is charged or credited, to the extent possible. If the HCA costs or credits cannot be passed through to the appropriate 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.
For further details please view Current Rates FRNs located under Marketing > FRNs