54588 Federal Register / Vol. 73, No. 184 / Monday, September 22, 2008 / Notices 

1WAPA–75 was approved by the Deputy 

Secretary of Energy on November 18, 1997 (62 FR 

63150), and confirmed and approved by FERC on 

a final basis on March 10, 1998, in Docket No. 

EF98–5041–000 (82 FERC 62164). 

2WAPA–98 was approved by the Secretary of 

Energy on September 13, 2002 (67 FR 60655), filed 

with FERC for informational purposes only, and 

docketed by FERC on September 24, 2002, in 

Docket No. EF02–5041–000. 

3WAPA–113 was approved by the Deputy 

Secretary of Energy on September 2, 2004 (69 FR 

55429), filed with FERC for informational purposes 

only, and docketed by FERC on September 3, 2004, 

in Docket No. EF04–5042–000. 

4WAPA–131 was approved by the Deputy 

Secretary of Energy on September 22, 2006 (71 FR 

57941), and filed with FERC for informational 

purposes only, and docketed by FERC on 

September 22, 2006, in Docket No. EF06–5042–000. 

adequately represented by any other 

parties. You do not need intervenor 

status to have your environmental 

comments considered. 

Availability of Additional Information 

Additional information about the 

project is available from the 

Commission’s Office of External Affairs, 

at 1–866–208–FERC or on the FERC 

Internet Web site (http://www.ferc.gov) 

using the eLibrary link. Click on the 

eLibrary link, click on ‘‘General Search’’ 

and enter the docket number excluding 

the last three digits in the Docket 

Number field. Be sure you have selected 

an appropriate date range. For 

assistance, please contact FERC Online 

Support at FercOnlineSupport@ferc.gov 

or toll free at 1–866–208–3676, or for 

TTY, contact (202) 502–8659. The 

eLibrary link also provides access to the 

texts of formal documents issued by the 

Commission, such as orders, notices, 

and rulemakings. 

In addition, the Commission now 

offers a free service called eSubscription 

which allows you to keep track of all 

formal issuances and submittals in 

specific dockets. This can reduce the 

amount of time you spend researching 

proceedings by automatically providing 

you with notification of these filings, 

document summaries and direct links to 

the documents. Go to http:// 

www.ferc.gov/esubscribenow.htm. 

Finally, public meetings or site visits 

will be posted on the Commission’s 

calendar located at http://www.ferc.gov/ 

EventCalendar/EventsList.aspx along 

with other related information. 

Kimberly D. Bose, 

Secretary. 

[FR Doc. E8–22008 Filed 9–19–08; 8:45 am] 

BILLING CODE 6717–01–P 

DEPARTMENT OF ENERGY 

Western Area Power Administration 

Parker-Davis Project-Rate Order No. 

WAPA–138 

AGENCY: Western Area Power 

Administration, DOE. 

ACTION: Notice of Order Concerning 

Firm Electric and Transmission Service 

Formula Rates. 

SUMMARY: The Deputy Secretary of 

Energy confirmed and approved Rate 

Order No. WAPA–138 and Rate 

Schedules PD–F7, PD–FT7, PD–FCT7, 

and PD–NFT7 placing firm electric and 

transmission service formula rates for 

the Parker-Davis Project (P–DP) of the 

Western Area Power Administration 

(Western) into effect on an interim basis. 

The provisional rates will be in effect 

until the Federal Energy Regulatory 

Commission (FERC) confirms, approves, 

and places them into effect on a final 

basis or until they are replaced by other 

rates. The provisional formula rates will 

provide sufficient revenue to pay all 

annual costs, including interest 

expense, and repayment of investment, 

within the allowable periods. 

DATES: Rate Schedules PD–F7, PD–FT7, 

PD–FCT7, and PD–NFT7 will be placed 

into effect on an interim basis on the 

first day of the first full billing period 

beginning on or after October 1, 2008, 

and will be in effect until FERC 

confirms, approves, and places the rate 

schedules in effect on a final basis 

through September 30, 2013, or until the 

rate schedule is superseded. 

FOR FURTHER INFORMATION CONTACT: Mr. 

J. Tyler Carlson, Regional Manager, 

Desert Southwest Customer Service 

Region, Western Area Power 

Administration, P.O. Box 6457, 

Phoenix, AZ 85005–6457, (602) 605– 

2453, carlson@wapa.gov, or Mr. Jack 

Murray, Rates Manager, Desert 

Southwest Customer Service Region, 

Western Area Power Administration, 

P.O. Box 6457, Phoenix, AZ 85005– 

6457, (602) 605–2442, 

jmurray@wapa.gov. 

SUPPLEMENTARY INFORMATION: Rate 

Schedules PD–F6, PD–FT6, PD–FCT6, 

and PD–NFT6 were approved under 

Rate Order No. WAPA–75 for the period 

beginning November 1, 1997, and 

ending September 30, 2002.1 These rate 

schedules were extended through 

September 30, 2004, by the approval of 

Rate Order No. WAPA–98 on September 

13, 2002.2 These rate schedules were 

extended again through September 30, 

2006, by the approval of Rate Order No. 

WAPA–113 approved on September 2, 

2004.3 These rate schedules were 

extended again through September 30, 

2008, by Rate Order No. WAPA–131 

approved on September 22, 2006.4

Rate Schedule PD–F6 for firm electric 

service is being superseded by Rate 

Schedule PD–F7. Under Rate Schedule 

PD–F7, the capacity rate is $17.45 per 

kilowattyear (kWyear), and the energy 

rate is 3.32 mills per kilowatthour 

(mills/kWh). The provisional rates in 

Rate Schedule PD–F7 equal the existing 

rates under Rate Schedule PD–F6. 

Rate Schedules PD–FT6 and PD–FCT6 

for firm point-to-point transmission 

service and firm transmission of Salt 

Lake City Area/Integrated Projects 

power are being superseded by Rate 

Schedules PD–FT7 and PD–FCT7. The 

provisional transmission rates under 

Rate Schedules PD–FT7 and PD–FCT7 

are $12.96/kWyear, which is equal to 

the existing rates under Rate Schedules 

PD–FT6 and PD–FCT6. 

Rate Schedule PD–NFT6 for nonfirm 

transmission service is being 

superseded by Rate Schedule PD–NFT7. 

Under Rate Schedule PD–NFT6, the 

existing nonfirm transmission rate is 

2.47 mills/kWh. The provisional 

nonfirm transmission rate under Rate 

Schedule PD–NFT7 is 1.48 mills/kWh. 

A change to the existing formula for 

calculating the nonfirm transmission 

rate resulted in a 40 percent decrease 

when compared to the existing rate. The 

modification to the nonfirm 

transmission rate formula ensures that 

the nonfirm transmission rate will not 

exceed the firm transmission rate. 

By Delegation Order No. 00–037.00, 

effective December 6, 2001, the 

Secretary of Energy delegated: (1) The 

authority to develop power and 

transmission rates to Western’s 

Administrator; (2) the authority to 

confirm, approve, and place such rates 

into effect on an interim basis to the 

Deputy Secretary of Energy; and (3) the 

authority to confirm, approve, and place 

into effect on a final basis, to remand or 

to disapprove such rates to FERC. 

Existing DOE procedures for public 

participation in power rate adjustments 

(10 CFR part 903) were published on 

September 18, 1985. 

Under Delegation Order Nos. 00– 

037.00 and 00–001.00C, 10 CFR part 

903, and 18 CFR part 300, I hereby 

confirm, approve, and place Rate Order 

No. WAPA–138, the proposed P–DP 

firm electric and transmission service 

formula rates, into effect on an interim 

basis. The new Rate Schedules PD–F7, 

PD–FT7, PD–FCT7, and PD–NFT7 will 

be promptly submitted to FERC for 

confirmation and approval on a final 

basis. 


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Dated: September 12, 2008. 

Jeffery F. Kupfer, 

Acting Deputy Secretary. 

Department of Energy 

Deputy Secretary 

Rate Order No. WAPA–138. 

In the matter of: Western Area Power 

Administration Rate Adjustment for the 

Parker-Davis Project Firm Electric and 

Transmission Service Formula Rates: 

Order Confirming, Approving, and 

Placing the Parker-Davis Project Firm 

Electric and Transmission Service 

Formula Rates Into Effect on an Interim 

Basis 

These rates were established in 

accordance with section 302 of the 

Department of Energy (DOE) 

Organization Act (42 U.S.C. 7152). This 

Act transferred to and vested in the 

Secretary of Energy the power marketing 

functions of the Secretary of the 

Department of the Interior and the 

Bureau of Reclamation under the 

Reclamation Act of 1902 (ch. 1093, 32 

Stat. 388), as amended and 

supplemented by subsequent laws, 

particularly section 9(c) of the 

Reclamation Project Act of 1939 (43 

U.S.C. 485h(c)), and other Acts that 

specifically apply to the project 

involved. 

By Delegation Order No. 00–037.00, 

effective December 6, 2001, the 

Secretary of Energy delegated: (1) The 

authority to develop power and 

transmission rates to Western’s 

Administrator; (2) the authority to 

confirm, approve, and place such rates 

into effect on an interim basis to the 

Deputy Secretary of Energy; and (3) the 

authority to confirm, approve, and place 

into effect on a final basis, to remand or 

to disapprove such rates to the Federal 

Energy Regulatory Commission (FERC). 

Existing DOE procedures for public 

participation in power rate adjustments 

(10 CFR part 903) were published on 

September 18, 1985. 

Acronyms and Definitions 

As used in this Rate Order, the 

following acronyms and definitions 

apply: 

Administrator: The Administrator of the 

Western Area Power Administration. 

Capacity: The electric capability of a 

generator, transformer, transmission 

circuit, or other equipment. It is 

expressed in kilowatts. 

Capacity Rate: The rate which sets forth 

the charges for capacity. It is 

expressed in dollars per killowattyear 

and applied to each kW of 

reservation. 

CME: Capitalized Moveable Equipment. 

Customer: An entity with a contract that 

is receiving firm electric service or 

transmission service from the ParkerDavis Project. 

DOE: United States Department of 

Energy. 

DOE Order RA 6120.2: An order 

outlining power marketing 

administration financial reporting and 

ratemaking procedures. 

Energy: Measured in terms of the work 

it is capable of doing over a period of 

time. It is expressed in kilowatthours. 

Energy Rate: The rate which sets forth 

the charges for energy. It is expressed 

in mills per kilowatthour and applied 

to each kilowatthour of reservation. 

FERC: The Federal Energy Regulatory 

Commission. 

Firm: A type of product and/or service 

guaranteed to be available in 

accordance with the terms of the 

contract. 

FRN: Federal Register notice. 

FY: Fiscal year; October 1 to September 

30. 

kW: Kilowatt—the electrical unit of 

capacity that equals 1,000 watts. 

kWh: Kilowatthour—the electrical unit 

of energy that equals 1,000 watts in 1 

hour. 

kWyear: Kilowattyear—the electrical 

unit of the yearly amount of capacity. 

Mill: A monetary denomination of the 

United States that equals one tenth of 

a cent or one thousandth of a dollar. 

Mills/kWh: Mills per kilowatthour—a 

unit of charge for energy. 

Nonfirm: A type of product and/or 

service not always available at the 

time requested by the Customer. 

O&M: Operation and Maintenance. 

MWD: The Metropolitan Water District 

of Southern California. 

P–DP: The Parker-Davis Project. 

Power: Capacity and energy. 

Proposed Rate: A rate that has been 

recommended by Western to the 

Deputy Secretary of the DOE for 

approval. 

Provisional Rate: A rate which has been 

confirmed, approved, and placed into 

effect on an interim basis by the 

Deputy Secretary of the DOE. 

PRS: Power Repayment Study. 

Rate Brochure: A document explaining 

the rationale and background for the 

rate proposal contained in this Rate 

Order. 

Reclamation: United States Department 

of the Interior, Bureau of Reclamation. 

Reclamation Law: A series of Federal 

laws. Viewed as a whole, these laws 

create the originating framework 

under which Western markets power. 

Revenue Requirement: The revenue 

required to recover annual expenses, 

such as O&M, purchase power, 

transmission service expenses, 

interest, deferred expenses, 

repayment of Federal investments, 

and other assigned costs. 

SCADA: Supervisory Control and Data 

Acquisition. 

SLCA/IP: Salt Lake City Area/Integrated 

Projects—the resources of the 

Collbran, Dolores, Rio Grande, and 

Seedskadee projects blended together 

with the CRSP to create the SLCA/IP. 

Supporting Documentation: A 

compilation of data and documents 

that support the Rate Brochure and 

the rate proposal. 

Western: United States Department of 

Energy, Western Area Power 

Administration. 

Effective Date 

The new interim formula rates will 

take effect on the first day of the first 

full billing period beginning on or after 

October 1, 2008, and will remain in 

effect until September 30, 2013, pending 

approval by FERC on a final basis. 

Public Notice and Comment 

Western followed the Procedures for 

Public Participation in Power and 

Transmission Rate Adjustments and 

Extensions, 10 CFR part 903, in 

developing these formula rates. The 

proposed action constituted a minor rate 

adjustment as defined by 10 CFR part 

903.2. As such, Western determined that 

it was not necessary to hold public 

information or comment forums. The 

steps Western took to involve interested 

parties in the rate process were: 

1. On October 11, 2007, Western’s 

Desert Southwest Region mailed a 

notice announcing an informal meeting 

to the P–DP customers and interested 

parties. The informal meeting was held 

November 14, 2007, in Phoenix, 

Arizona. At this informal meeting, 

Western explained the rationale for the 

rate adjustment, presented options for 

the proposed formula rates, and 

answered questions. 

2. On December 14, 2007, Western’s 

Desert Southwest Region e-mailed the 

P–DP customers and interested parties 

to provide the Web site address to 

obtain the supplemental information 

that was requested by the customers at 

the informal meeting held November 14, 

2007. 

3. On February 1, 2008, Western’s 

Desert Southwest Region mailed a 

notice announcing a second informal 

meeting to the P–DP customers and 

interested parties. The second informal 

meeting was held March 12, 2008, in 

Phoenix, Arizona. At this informal 

meeting, Western explained the minor 

rate adjustment process and presented 

proposed formula rates that included 


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customer input from the informal 

meeting held November 14, 2008. 

4. An FRN published on April 29, 

2008 (73 FR 23248), announced the 

proposed formula rates. This notice 

began a public consultation and 

comment period. 

5. On May 1, 2008, Western’s Desert 

Southwest Region e-mailed the FRN (73 

FR 23248) to the P–DP customers and 

interested parties and provided the Web 

site address to obtain a copy of the Rate 

Brochure and supporting 

documentation. 

6. Western received one comment 

letter during the consultation and 

comment period, which ended on May 

29, 2008. All formally submitted 

comments have been considered in 

preparing this Rate Order. 

Comments 

Written comments were received from 

the Irrigation & Electrical Districts 

Association of Arizona. 

Project Description 

The P–DP was formed by 

consolidating two projects, Parker Dam 

and Davis Dam, under the terms of the 

Act of May 28, 1954. All facilities of the 

P–DP were operated and maintained by 

Reclamation until the formation of the 

Department of Energy pursuant to the 

Department of Energy Organization Act 

(DOE Act). Pursuant to the DOE Act, 

responsibility for the power marketing 

functions of Reclamation, including the 

construction, operation, and 

maintenance of substations, 

transmission lines, and attendant 

facilities, was transferred to the DOE. 

The responsibility for operation and 

maintenance of the dams and 

powerplants remains with Reclamation. 

Parker Dam, which created Lake 

Havasu 155 miles below Hoover Dam on 

the Colorado River, was authorized by 

the Rivers and Harbors Act of August 

30, 1935. Construction of Parker Dam 

began in 1934 and was completed in 

1942. Reclamation constructed the 

project partly with funds advanced by 

the MWD. MWD receives half of the 

capacity and energy from the four 

generating units at Parker Dam. 

Davis Dam, which created Lake 

Mohave 67 miles below Hoover Dam on 

the Colorado River, was authorized 

under the Reclamation Project Act of 

1939. Construction began in 1941, but 

due to construction delays caused by 

World War II, it was not completed until 

1953. Davis Dam has five generating 

units. 

Power generated from the P–DP is 

marketed to customers in Arizona, 

Nevada, and California. Excluding 

project use, the marketing period 

effective FY 2009 provides for 198,337 

kW of capacity in the winter season and 

259,206 kW of capacity in the summer 

season. Customers receive 1,703 kWh 

per kW in the winter season and 3,441 

kWh per kW in the summer season. 

The P–DP transmission system 

includes 48 substations and over 1,500 

circuit miles of transmission lines in 

Arizona, southern Nevada, and along 

the Colorado River in California. 

Power Repayment Study 

Western prepares a PRS each FY to 

determine if revenues will be sufficient 

to repay, within the required time, all 

costs assigned to the P–DP. Repayment 

criteria are based on law, policies, 

including DOE Order RA 6120.2, and 

authorizing legislation. 

The provisional formula rates under 

Rate Schedules, PD–F7, PD–FT–7, and 

PD–FCT7 are equal to the existing rates. 

The provisional firm electric service 

capacity rate under Rate Schedule PD– 

F7 is $17.45 per kWyear. The 

provisional firm electric service energy 

rate under Rate Schedule PD–F7 is 3.32 

mills per kWh. The provisional firm 

point-to-point transmission service rate 

under Rate Schedule PD–FT7 is $12.96 

per kWyear. The provisional firm 

transmission service rate for 

transmission of SLCA/IP power under 

Rate Schedule PD–FCT7 is $12.96 per 

kWyear. Under Rate Schedule PD– 

NFT7, the provisional rate for nonfirm 

transmission service will result in a rate 

decrease of 40 percent when compared 

to the existing rate. The existing rate for 

nonfirm transmission service under Rate 

Schedule PD–NFT6 is 2.47 mills per 

kWh. The provisional rate for nonfirm 

transmission service under Rate 

Schedule PD–NFT7 is 1.48 mills per 

kWh. 

Existing and Provisional Rates 

A comparison of the existing and 

provisional firm electric and 

transmission service rates follows: 

PARKER-DAVIS PROJECT COMPARISON OF EXISTING AND PROVISIONAL RATES

Service Existing rates 

Provisional 

rates 

(effective 

10/01/08) 

Change 

Firm Electric Service—Capacity ($/kWyear) ............................................................................... $17.45 $17.45 0% 

Firm Electric Service—Energy (mills/kWh) .................................................................................. 3.32 3.32 0% 

Firm Point-to-Point Transmission ($/kWyear) ............................................................................. $12.96 $12.96 0% 

Firm Transmission of SLCA/IP Power ($/kWyear) ...................................................................... $12.96 $12.96 0% 

Nonfirm Transmission (mills/kWh) ............................................................................................... 2.47 1.48 (40%) 

Certification of Rates 

Western’s Administrator certified that 

the provisional rates for P–DP firm 

electric and transmission service are the 

lowest possible rates consistent with 

sound business principles. The 

provisional rates were developed 

following administrative policies and 

applicable laws. 

Firm Electric and Transmission Service 

Formula Rates Discussion 

According to Reclamation Law, 

Western must establish power and 

transmission rates sufficient to recover 

operation, maintenance, purchased 

power expenses, interest expenses, and 

repayment of power investment and 

irrigation aid. 

Formula rates for P–DP firm electric 

and transmission service are calculated 

annually. Under the rate methodology, 

costs that are readily identifiable as 

supporting either generation or 

transmission functions are directly 

allocated to generation or transmission 

revenue requirements. All other costs 

are apportioned between generation and 

transmission revenue requirements 

based on cost allocation factors. Existing 

cost allocation factors include SCADA, 

CME, percentage allocation of Western 

O&M, labor hours devoted to billing, 

and historic project investment. 

Western will modify the existing rate 

methodology by eliminating the CME, 

labor hours devoted to billing, and 

historic project investment cost 

allocation factors. Western will 

implement a new cost allocation factor 

that is the ratio of the number of 

customers receiving firm electric or 


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transmission service to the total number of customers. A comparison of the 

affected cost allocation factors follows: 

PARKER-DAVIS PROJECT COMPARISON OF COST ALLOCATION FACTORS

Cost Existing factor Proposed factor 

Systemwide (Billing and Finance) ...................... Billing Hours ..................................................... Ratio of Customers. 

Operations/Dispatch ........................................... SCADA/Billing Hours ....................................... SCADA. 

CME .................................................................... CME Calculation .............................................. Percentage Allocation of Western O&M. 

Western Principal & Interest ............................... Historic Investment .......................................... None (Allocated to Transmission Only). 

Western prepared a detailed impact 

analysis that determined, over the last 

seven years, the cost allocation factor 

changes would have resulted in an 

average annual change to either the 

transmission or generation revenue 

requirements of approximately $388,000 

or 0.96%. At this time, the firm electric 

service and firm transmission service 

rates resulting from the modifications to 

the rate methodology are equal to 

existing rates and will provide sufficient 

revenue to recover generation and 

transmission revenue requirements. The 

nonfirm transmission rate is being 

decreased due to a change in the rate 

formula, and as a result, it will not 

exceed the firm point-to-point 

transmission rate. The change in the 

nonfirm transmission rate is 

independent of the changes to the cost 

allocation factors. 

During informal discussions prior to 

the commencement of the rate 

adjustment process, Western received a 

request from customers to modify the 

billing practices for P–DP long-term firm 

transmission service. In the request, the 

customers noted that payments for firm 

electric service are required one month 

in advance of service and suggested that 

all parties be subject to the same billing 

terms and conditions. 

Existing billing practices for P–DP 

long-term firm transmission service 

allow customers to pay after the fact, 

usually one month after service is 

provided. Additionally, the P–DP rate 

calculations assume the full and timely 

collection of revenues. To the extent 

that customer payments are late or 

uncollectible, rates may be insufficient 

to recover revenue requirements. This 

could result in a rate increase, adversely 

affecting all P–DP customers. In 

response to the customers’ request, 

Western will modify the billing 

practices so that customers will be 

required to pay for P–DP long-term firm 

transmission service one month in 

advance of service. This requirement is 

incorporated into Rate Schedules PD– 

FT7 and PD–FCT7. 

Statement of Revenue and Related 

Expenses 

The following table provides a 

summary of projected revenue and 

expense data for the firm electric and 

transmission services formula rates 

through the 5-year provisional rate 

approval period. 

PARKER-DAVIS PROJECT COMPARISON OF 5-YEAR RATE PERIOD (FY 2009–FY 2013) TOTAL REVENUES AND EXPENSES

Existing rates 

($000) 

Provisional 

rates 

($000) 

Difference 

($000) 

Total Revenues 1 ......................................................................................................................... $295,256 $295,256 $0 

Revenue Distribution 

Expenses: 

O&M ...................................................................................................................................... 161,701 161,701 0 

Purchased Power and Wheeling .......................................................................................... 21,043 21,043 0 

Interest .................................................................................................................................. 86,266 86,266 0 

Other ..................................................................................................................................... 7,282 7,282 0 

Total Expenses .............................................................................................................. 276,292 276,292 0 

Principal Payments: 

Capitalized Expenses ........................................................................................................... 0 0 0 

Original Project and Additions .............................................................................................. 110 110 0 

Replacements ....................................................................................................................... 18,804 18,804 0 

Irrigation ................................................................................................................................ 50 50 0 

Total Principal Payments .............................................................................................. 18,964 18,964 0 

Total Revenue Distribution ............................................................................................ 295,256 295,256 0 

1Total revenues include approximately $41,625,000 of available revenues from prior periods. 

Basis for Rate Development 

The existing formula rates for P–DP 

firm electric and transmission service 

under Rate Schedules PD–F6, PD–FT6, 

PD–FCT6, and PD–NFT6 expire 

September 30, 2008. The provisional 

formula rates will provide sufficient 

revenue to pay all annual costs, 

including interest expense, and 

repayment of power investment and 

irrigation aid within the allowable 

periods. The provisional formula rates 

will take effect on October 1, 2008, to 

correspond with the start of the Federal 

fiscal year, and will remain in effect 

through September 30, 2013. 

Comments 

The comments and responses 

regarding the firm electric and 

transmission service rates, paraphrased 

for brevity when not affecting the 

meaning of the statement(s), are 

discussed below. 

A. Comment: An interested party 

made a statement with regard to Senate 


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Bill S.2739. Section 513 of that bill 

contains post-September 11, 2001, 

security cost legislation which specifies 

the amount of security costs which will 

be considered non-reimbursable. The 

Interested Party requested that Western 

and Reclamation adjust their budgets to 

account for the legislation. 

Response: Senate Bill S.2739 was 

signed into law on May 8, 2008. 

Reclamation is in the process of 

determining which costs in these rate 

calculations will be deemed nonreimbursable under the new law. Any 

security costs ultimately deemed nonreimbursable will be carried into the 

next fiscal year, reducing FY 2010 

revenue requirements. 

B. Comment: An interested party 

sought assurance that the firm electric 

and transmission service formula rates 

will include hydrologic data to be 

collected by Reclamation in July of 

2008. 

Response: Generation and purchase 

power forecasts used in the firm electric 

and transmission service formula rates 

are based on the most recent Annual 

Operating Plan (AOP) produced by 

Western and presented to the customers. 

The FY 2009 AOP, used to calculate the 

rates, was based on hydrologic data 

released by Reclamation on April 7, 

2008. Additional revenues or expenses 

resulting from changes in hydrology 

will be included in the annual rate 

calculation for the subsequent year. 

Availability of Information 

Information about this rate 

adjustment, including power repayment 

studies, comments, letters, 

memorandums, and other supporting 

material made or kept by Western and 

used to develop the provisional rates, is 

available for public review in the Desert 

Southwest Regional Office, Western 

Area Power Administration, 615 South 

43rd Avenue, Phoenix, Arizona. 

Ratemaking Procedure Requirements 

Determination Under Executive Order 

12866 

Western has an exemption from 

centralized regulatory review under 

Executive Order 12866; accordingly, no 

clearance of this notice by the Office of 

Management and Budget is required. 

Submission to the Federal Energy 

Regulatory Commission 

The interim formula rates herein 

confirmed, approved, and placed into 

effect, together with supporting 

documents, will be submitted to FERC 

for confirmation and final approval. 

Order 

In view of the above and under the 

authority delegated to me, I confirm and 

approve on an interim basis, effective 

October 1, 2008, Rate Schedules PD–F7, 

PD–FT7, PD–FCT7, and PD–NFT7 for 

the Parker-Davis Project of the Western 

Area Power Administration. The rate 

schedules shall remain in effect on an 

interim basis, pending FERC’s 

confirmation and approval of them or 

substitute rates on a final basis through 

September 30, 2013. 

Dated: September 12, 2008. 

Jeffery F. Kupfer, 

Acting Deputy Secretary. 

Rate Schedule PD–F7 (Supersedes 

Schedule PD–F6). 

United States Department of Energy 

Western Area Power Administration 

Parker-Davis Project; Schedule of Rates 

for Firm Electric Service 

Effective 

The first day of the first full billing 

period beginning on or after October 1, 

2008, through September 30, 2013, or 

until superseded, whichever occurs 

earlier. 

Available 

In the area served by the Parker-Davis 

Project (P–DP). 

Applicable 

To firm electric service customers for 

firm power service supplied through 

one meter at one point of delivery, 

unless otherwise provided by service 

agreement or contract. 

Character and Conditions of Service 

Alternating current at 60 hertz, threephase, delivered and metered at the 

voltages and points of delivery 

established by service agreement or 

contract. 

Charges 

Energy Charge: Each firm electric 

service customer shall be billed monthly 

an energy charge. This charge is equal 

to the customer’s monthly contractual 

energy reservation multiplied by the 

Energy Rate, rounded to the penny. The 

Energy Rate shall be equal to 50 percent 

of the annual generation revenue 

requirement divided by the estimated 

total generation delivery commitments, 

rounded to two decimal places. 

Capacity Charge: Each firm electric 

service customer shall be billed monthly 

a capacity charge. This charge is equal 

to the customer’s monthly contractual 

capacity reservation multiplied by the 

Capacity Rate, rounded to the penny. 

The Capacity Rate shall be equal to 50 

percent of the annual generation 

revenue requirement divided by the 

estimated total generation delivery 

commitments, rounded to two decimal 

places. 

Transmission Charge: Each firm 

electric service customer shall be billed 

monthly a transmission charge. This 

charge is equal to the customer’s 

contractual reservation multiplied by 

the rate calculated in accordance with 

PD–FT7, rounded to the penny. 

Lower Basin Development Fund 

Contribution Charge: The contribution 

charge is 4.5 mills/kWh for each kWh 

measured or scheduled to an Arizona 

purchaser and 2.5 mills/kWh for each 

kWh measured or scheduled to a 

California or Nevada purchaser. 

Billing of Excess Energy 

For each month in which there is 

excess energy available, offered, and 

delivered to the firm electric service 

customer, such excess energy shall be 

billed at the Energy Rate. 

Billing for Unauthorized Overruns 

For each month in which there is a 

contract violation involving an 

unauthorized overrun of energy and/or 

capacity, such overruns shall be billed 

at 10 times the Energy and/or Capacity 

Rate in this rate schedule. For each 

month in which there is a contract 

violation involving an unauthorized 

overrun of transmission, such overrun 

shall be billed at two times the 

Transmission Charge in this rate 

schedule. 

Transformer Losses 

If delivery is made at transmission 

voltage but metered on the low-voltage 

side of the substation, the meter 

readings will be increased to 

compensate for transformer losses as 

provided for in the contract. 

Power Factor 

The firm electric service customer 

will normally be required to maintain a 

power factor at all points of 

measurement between 95-percent 

lagging and 95-percent leading. 

Rate Schedule PD–FT7 (Supersedes 

Schedule PD–FT6). 

United States Department of Energy 

Western Area Power Administration 

Parker-Davis Project; Schedule of Rates 

for Firm Point-to-Point Transmission 

Service 

Effective 

The first day of the first full billing 

period beginning on or after October 1, 

2008, through September 30, 2013, or 


sroberts on PROD1PC70 with NOTICES
Federal Register / Vol. 73, No. 184 / Monday, September 22, 2008 / Notices 54593 

until superseded, whichever occurs 

earlier. 

Available 

In the area served by the Parker-Davis 

Project (P–DP). 

Applicable 

To firm point-to-point transmission 

service customers where capacity and 

energy are supplied to the P–DP system 

at points of interconnection with other 

systems and transmitted and delivered, 

less losses, to points of delivery on the 

P–DP system. 

Character and Conditions of Service 

Alternating current at 60 hertz, threephase, delivered and metered at the 

voltages and points of delivery 

established by service agreement or 

contract. 

Long-Term Rate 

For transmission service one year or 

longer, the annual rate for each kilowatt 

per year is equal to the annual 

transmission revenue requirement 

divided by the estimated transmission 

delivery commitments, rounded to the 

nearest 12 cent increment. The annual 

rate for long-term service is payable 

monthly at a rate for each kilowatt per 

month equal to the annual rate for longterm service divided by 12. 

Short-Term Rates 

For transmission service up to one 

year, the maximum rate for each kW is 

as follows: 

Monthly: Equal to the annual longterm rate, divided by 12 and rounded to 

two decimal places. 

Weekly: Equal to the annual long term 

rate, divided by 52 and rounded to two 

decimal places. 

Daily: Equal to the annual long term 

rate, divided by 365 and rounded to two 

decimal places. 

Hourly: Equal to the annual long term 

rate, divided by 8,760 and rounded to 

five decimal places. 

Discounts may be offered from time to 

time in accordance with Western’s Open 

Access Transmission Tariff. 

Billing 

Western will bill firm point-to-point 

transmission service customers monthly 

by applying the rates under this rate 

schedule to the amount of capacity 

reserved. Payment for service will be 

required one month in advance of 

service. 

Adjustments for Reactive Power 

There shall be no entitlement to 

transfer of reactive kilovolt-amperes at 

delivery points, except when such 

transfers may be mutually agreed upon 

by the customer and Western or their 

authorized representatives. 

Adjustments for Losses 

Capacity and energy losses incurred 

in connection with the transmission and 

delivery of capacity and energy under 

this rate schedule shall be supplied by 

the customer in accordance with the 

service agreement or contract. 

Overrun of Capacity Reserved 

Western will assess a charge for 

unauthorized use of transmission 

service at a rate equal to two times the 

applicable rate for the service at issue. 

The charge will be applied to use in 

excess of the reservation amount, which 

shall be the difference between the 

amount of transmission service actually 

used by the customer less the amount of 

transmission service the customer has 

reserved. The customer will incur the 

charge for an overrun during the 

calendar month or for the period of 

transmission service if such service is 

for a term of less than one month. 

Rate Schedule PD–FCT7 (Supersedes 

Schedule PD–FCT6). 

United States Department of Energy 

Western Area Power Administration 

Parker-Davis Project; Schedule of Rate 

for Firm Transmission Service of Salt 

Lake City Area/Integrated Projects 

Power 

Effective 

The first day of the first full billing 

period beginning on or after October 1, 

2008, through September 30, 2013, or 

until superseded, whichever occurs 

earlier. 

Available 

In the area served by the Parker-Davis 

Project (P–DP). 

Applicable 

To Salt Lake City Area/Integrated 

Projects (SLCA/IP) southern division 

customers, where SLCA/IP capacity and 

energy are supplied to the P–DP system 

by the Colorado River Storage Project 

(CRSP) at points of interconnection with 

the CRSP system and transmitted and 

delivered on a uni-directional basis, less 

losses, to southern division customers at 

points of delivery on the P–DP system. 

Character and Conditions of Service 

Alternating current at 60 hertz, threephase, delivered and metered at the 

voltages and points of delivery 

established by service agreement or 

contract. 

Rate 

The annual rate for each kilowatt per 

year is equal to the annual transmission 

revenue requirement divided by the 

estimated transmission delivery 

commitments, rounded to the nearest 12 

cent increment. The annual rate is 

payable monthly at a rate for each 

kilowatt per month equal to the annual 

rate divided by 12. 

Billing 

Western will bill firm transmission 

service customers monthly by applying 

the rates under this rate schedule to the 

amount of capacity reserved. Payment 

for service will be required one month 

in advance of said service. 

Adjustments for Reactive Power 

There shall be no entitlement to 

transfer of reactive kilovolt-amperes at 

delivery points, except when such 

transfers may be mutually agreed upon 

by the customer and Western or their 

authorized representatives. 

Adjustments for Losses 

Capacity and energy losses incurred 

in connection with the transmission and 

delivery of capacity and energy under 

this rate schedule shall be supplied by 

the customer in accordance with the 

service agreement or contract. 

Overrun of Capacity Reserved 

Western will asses a charge for 

unauthorized use of transmission 

service at a rate equal to two times the 

applicable rate for the service at issue. 

The charge will be applied to use in 

excess of the reservation amount, which 

shall be the difference between the 

amount of transmission service actually 

used by the customer less the amount of 

transmission service the customer has 

reserved. The customer will incur the 

charge for an overrun during the 

calendar month or for the period of 

transmission service if such service is 

for a term of less than one month. 

Rate Schedule PD–NFT7 (Supersedes 

Schedule PD–NFT6). 

United States Department of Energy 

Western Area Power Administration 

Parker-Davis Project; Schedule of Rate 

for Nonfirm Transmission Service 

Effective 

The first day of the first full billing 

period beginning on or after October 1, 

2008, through September 30, 2013, or 

until superseded, whichever occurs 

earlier. 

Available 

In the area served by the Parker-Davis 

Project (P–DP). 


sroberts on PROD1PC70 with NOTICES
54594 Federal Register / Vol. 73, No. 184 / Monday, September 22, 2008 / Notices 

Applicable 

To nonfirm transmission service 

customers where capacity and energy 

are supplied to the P–DP system at 

points of interconnection with other 

systems and transmitted and delivered, 

less losses, to points of delivery on the 

P–DP system. 

Character and Conditions of Service 

Alternating current at 60 hertz, threephase, delivered and metered at the 

voltages and points of delivery 

established by service agreement or 

contract. 

Rate 

The nonfirm transmission service rate 

for each kilowatt per hour is equal to the 

annual transmission revenue 

requirement divided by the estimated 

transmission delivery commitments, 

divided by 8,760 and rounded to five 

decimal places. Discounts may be 

offered from time to time in accordance 

with Western’s Open Access 

Transmission Tariff. 

Billing 

Western will bill nonfirm 

transmission customers monthly by 

applying the nonfirm rate under this 

rate schedule to the amount of capacity 

reserved. 

Adjustments for Reactive Power 

There shall be no entitlement to 

transfer of reactive kilovolt-amperes at 

delivery points, except when such 

transfers may be mutually agreed upon 

by the customer and Western or their 

authorized representatives. 

Adjustments for Losses 

Capacity and energy losses incurred 

in connection with the transmission and 

delivery of capacity and energy under 

this rate schedule shall be supplied by 

the customer in accordance with the 

service agreement or contract. 

[FR Doc. E8–22096 Filed 9–19–08; 8:45 am] 

BILLING CODE 6450–01–P 

ENVIRONMENTAL PROTECTION 

AGENCY 

[EPA–HQ–OPP–2008–0143; FRL–8381–1] 

The Association of American Pesticide 

Control Officials/State FIFRA Issues 

Research and Evaluation Group 

(SFIREG) Working Committee on 

Pesticide Operations and 

Management; Notice of Public Meeting 

AGENCY: Environmental Protection 

Agency (EPA). 

ACTION: Notice. 

SUMMARY: The Association of American 

Pesticide Control Officials (AAPCO)/ 

State FIFRA Issues Research and 

Evaluation Group (SFIREG) Working 

Committee on Pesticide Operations and 

Management (WC/POM) will hold a 2– 

day meeting, beginning on October 6-7, 

2008 and ending October 7, 2008. This 

notice announces the location and times 

for the meeting and sets forth the 

tentative agenda topics. 

DATES: The meeting will be held on 

Monday, October 6, 2008 from 8:30 a.m. 

to 5 p.m. and 8:30 a.m. to 12 noon on 

Tuesday, October 7, 2008. 

To request accommodation of a 

disability, please contact the person 

listed under FOR FURTHER INFORMATON

CONTACT, preferably at least 10 days 

prior to the meeting, to give EPA as 

much time as possible to process your 

request. 

ADDRESSES: The meeting will be held at 

The Grove Hotel, 245 South Capitol 

Blvd., Boise, Idaho. 

FOR FURTHER INFORMATION CONTACT: Jim 

Roelofs, Field and External Affairs 

Division, (7506P), Office of Pesticide 

Programs, Environmental Protection 

Agency, 1200 Pennsylvania Ave., NW., 

Washington, DC 20460–0001; telephone 

number: (703) 308–2964; fax number: 

(703) 308–1850; e-mail address: 

roelofs.jim@epa.gov or Grier Stayton, 

SFIREG Executive Secretary, P.O. Box 

466, Milford, DE 19963; telephone 

number: (302) 422–8152; fax (302) 422– 

2435; e-mail address: aapcosfireg@comcast.net. 

SUPPLEMENTARY INFORMATION: 

I. General Information 

A. Does this Action Apply to Me? 

You may be potentially affected by 

this action if you are interested in 

SFIREG information exchange 

relationship with EPA regarding 

important issues related to human 

health, environmental exposure to 

pesticides, and insight into EPA’s 

decision-making process are invited and 

encouraged to attend the meetings and 

participate as appropriate. Potentially 

affected entities may include, but are 

not limited to, those persons who are or 

may be required to conduct testing of 

chemical substances under the Federal 

Food, Drug and Cosmetic Act (FFDCA), 

or the Federal Insecticide, Fungicide, 

and Rodenticide Act (FIFRA). 

B. How Can I Get Copies of this 

Document and Other Related 

Information? 

1. Docket. EPA has established a 

docket for this action under docket ID 

number EPA–HQ–OPP–2008–0143. 

Publicly available docket materials are 

available either in the electronic docket 

at http://www.regulations.gov, or, if only 

available in hard copy, at the Office of 

Pesticide Programs (OPP) Regulatory 

Public Docket in Rm. S–4400, One 

Potomac Yard (South Bldg.), 2777 S. 

Crystal Dr., Arlington, VA. The hours of 

operation of this Docket Facility are 

from 8:30 a.m. to 4 p.m., Monday 

through Friday, excluding legal 

holidays. The Docket Facility telephone 

number is (703) 305–5805. 

2. Electronic access. You may access 

this Federal Register document 

electronically through the EPA Internet 

under the ‘‘Federal Register’’ listings at 

http://www.epa.gov/fedrgstr. 

II. Background 

1. Discussion on risk mitigation 

measures for soil fumigants. 

2. Follow up report on updated spray 

drift language for agricultural 

pyrethroids. 

3. State concerns with proposed 

labeling changes for picloram. 

4. Refining a system for SFIREG/POM 

review of proposed pesticide labeling. 

5. Improving groundwater advisory 

statements on pesticide labels. 

6. Developing acceptable, boiler plate 

language to replace ‘‘For Use By’’ 

statements. 

7. Risk of eye injury from certain 2,4- 

D products. 

8. Food safety issues following 

pesticide misuse. 

9. EPA Update/Briefing. 

a. Office of Pesticide Programs 

Update. 

b. Office of Enforcement 

Compliance Assurance Update. 

10. POM Working Committee 

Workgroups Issue Papers/Updates. 

List of Subjects 

Environmental protection, 

Dated: September 4, 2008. 

William R. Diamond, 

Director, Field and External Affairs Division, 

Office of Pesticide Programs 

[FR Doc. E8–22077 Filed 9–19–08; 8:45 am] 

BILLING CODE 6560–50–S 

FEDERAL COMMUNICATIONS 

COMMISSION 

Public Information Collections 

Approved by Office of Management 

and Budget 

September 8, 2008. 

SUMMARY: The Federal Communications 

Commission (FCC) has received Office 

of Management and Budget (OMB) 


sroberts on PROD1PC70 with NOTICES