Rates

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 2008 Revenue Requirement/Rates

Applicable
Rate Schedule

Oct 07 - Mar 08

Apr 08 � Sept 08

Power Revenue Requirement (Oct 2007 – Sep 2008)
(for First Preference and Base Resource)

$ 79,882,665

$ 72,541,807

CV-F12

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

	Oct 07 � Mar 08	Apr 08 � Sept 08
Sierra CC	0.41%	0.41%
Calaveras PPA	0.98%	0.98%
Trinity PUD	3.16%	3.16%
Tuolumne PPA	0.87%	0.87%
Total	5.42%	5.42%

First Preference Revenue Requirement

$ 4,329,640

$ 3,931,766

CV-F12

Base Resource Revenue Requirement
Oct 07 � Mar 08 Monthly
Apr 08 � Sep 08 Monthly

$ 75,553,025
$ 3,148,043
$ 9,444,128

$ 68,610,041
$ 3,148,043
$ 8,286,964

CV-F12

Custom Product Power

Pass-through
of all costs

CPP-1

CVP TRANSMISSION	Rates (effective October 1, 2007 through March 31, 2008)	Rates (effective April 1, 2008)	Applicable Rate Schedule
CVP Transmission Rate - monthly ($/kW-Month)	$ 1.13	$ 1.15	CV-T2
CVP Transmission Rate - hourly (mills/kWh)	1.54	1.57	CV-T2
CVP Transmission Rate - daily (mills/kW-day)	36.98	37.63	CV-T2
CVP Network Integrated Transmission Service (NITS) Revenue Requirement ($/month)	$ 2,046,703	$ 2,036,501	CV-NWT4

PACI TRANSMISSION -- Spring Rate for April 2008 – May 2008		Applicable Rate Schedule
PACI Pt-to-Pt (mills/kW-Day)	31.90	PACI-T2
PACI Pt-to-Pt ($/kW-Day)	$ 0.0319
PACI Pt-to-Pt ($/MW-Day)	$ 31.90
PACI Pt-to-Pt ($/MW-Month)	$ 973.00
PACI Pt-to-Pt ($/MWh)	$ 1.33

PACI TRANSMISSION -- Winter Rate for November 2007 – March 2008	Rates (effective 11/1/07)	Applicable Rate Schedule
PACI Pt-to-Pt (mills/kW-Day)	29.17	PACI-T2
PACI Pt-to-Pt ($/kW-Day)	$ 0.0292
PACI Pt-to-Pt ($/MW-Day)	$ 29.17
PACI Pt-to-Pt ($/MW-Month)	$881.00
PACI Pt-to-Pt ($/MWh)	$ 1.22

PACI TRANSMISSION -- Summer Rate for June 2008 – October 2008		Applicable Rate Schedule
PACI Pt-to-Pt (mills/kW-Day)	30.46	PACI-T2
PACI Pt-to-Pt ($/kW-Day)	$ 0.0305
PACI Pt-to-Pt ($/MW-Day)	$ 30.46
PACI Pt-to-Pt ($/MW-Month)	$ 932.00
PACI Pt-to-Pt ($/MWh)	$ 1.27

COTP TRANSMISSION – Spring Rate for April 2008 - May 2008		Applicable Rate Schedule
COTP Pt-to-Pt (mills/kW-Day)	64.85	COTP-T2
COTP Pt-to-Pt ($/kW-Day)	$ 0.06485
COTP Pt-to-Pt ($/MW-Day)	$ 64.85
COTP Pt-to-Pt ($/MW-Month)	$ 1,978.00
COTP Pt-to-Pt ($/MWh)	$ 2.70

COTP TRANSMISSION – Winter Rate for November 2007 – March 2008		Applicable Rate Schedule
COTP Pt-to-Pt (mills/kW-Day)	64.44	COTP-T2
COTP Pt-to-Pt ($/kW-Day)	$ 0.06444
COTP Pt-to-Pt ($/MW-Day)	$ 64.44
COTP Pt-to-Pt ($/MW-Month)	$ 1,946.00
COTP Pt-to-Pt ($/MWh)	$ 2.68

COTP TRANSMISSION – Summer Rate for June 2008 - October 2008		Applicable Rate Schedule
COTP Pt-to-Pt (mills/kW-Day)	67.12	COTP-T2
COTP Pt-to-Pt ($/kW-Day)	$ 0.06712
COTP Pt-to-Pt ($/MW-Day)	$ 67.12
COTP Pt-to-Pt ($/MW-Month)	$ 2,054.00
COTP Pt-to-Pt ($/MWh)	$ 2.80

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

ANCILLARY SERVICES	Rates (effective October 1, 2007)	Applicable Rate Schedule
Regulation and Frequency Response (kW-month)	$ 3.97	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 (underdelivery) 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