Federal Register / Vol. 73, No. 184 / Monday, September 22, 2008 / Notices 54573 

a result of the public scoping process. 

The environmental issues include: 

(1) Atmospheric Resources: Potential 

air quality impacts resulting from air 

emissions during construction and 

operation of the proposed Kemper 

County IGCC Project and the connected 

actions (e.g., effects of ground-level 

concentrations of criteria pollutants and 

trace metals including mercury, on 

surrounding areas, including those of 

special concern such as Prevention of 

Significant Deterioration Class I areas). 

Potential effects of greenhouse gas 

emissions. 

(2) Water Resources: Potential effects 

of groundwater withdrawals and 

discharges of effluents to surface waters. 

Potential water resources impacts 

resulting from construction and 

operation of the connected actions. 

(3) Infrastructure and Land Use: 

Potential effects on existing 

infrastructure and land uses resulting 

from the construction and operation of 

the proposed IGCC project and 

connected action facilities. For example, 

potential traffic effects resulting from 

the proposed project and potential land 

use impacts of committing land to 

power plant or temporary land use 

impacts of mining. 

(4) Solid Waste: Pollution prevention 

and waste management issues, 

including potential solid waste impacts 

caused by the generation, treatment, 

transport, storage, and management of 

ash and solid wastes. 

(5) Visual: Potential aesthetic impacts 

associated with new stacks, mechanicaldraft cooling tower, two flare derricks, 

and other plant structures included in 

the IGCC plant and from the connected 

actions. 

(6) Floodplain: Potential impacts (e.g., 

impeding floodwaters, re-directing 

floodwaters, onsite property damage) of 

siting structures and infrastructure 

within a floodplain. 

(7) Wetlands: Potential effects to 

wetlands due to construction and 

operation of the power plant and the 

connected action facilities. 

(8) Ecological: Potential onsite and 

offsite impacts to vegetation, terrestrial 

wildlife, aquatic wildlife, threatened 

and endangered species (other than 

broadly distributed and wide ranging 

species such as the bald eagle and redcockaded woodpecker, the threatened 

Price’s potato bean is the only Federally 

protected species known to occur in 

Kemper County), and ecologically 

sensitive habitats due to the 

construction and operation of the power 

plant and connected actions. 

(9) Safety and Health: Constructionrelated safety, process safety, and 

management of process chemicals and 

materials. 

(10) Construction: Potential impacts 

associated with noise, traffic patterns, 

and construction-related emissions. 

(11) Community Impacts: Potential 

congestion and other impacts to local 

traffic patterns; socioeconomic impacts 

on public services and infrastructure 

(e.g., police protection, schools, and 

utilities); noise associated with project 

operation; and environmental justice 

issues with respect to the surrounding 

community. 

(12) Cultural and Archaeological 

Resources: Potential impacts to such 

resources associated with construction 

of the project and connected actions. 

(13) Cumulative Effects: The 

incremental impacts of the proposed 

project (e.g., incremental air emissions 

affecting ambient air quality) when 

added to other past, present, and 

reasonably foreseeable future actions, 

including the connected actions. This 

analysis will include potential impacts 

on global climate change. 

The level of analysis of issues 

analyzed in the EIS will be in 

accordance with their level of 

importance and as determined by the 

scoping process. The most detailed 

analyses are tentatively expected to 

focus on potential impacts on air 

resources, cultural and archaeological 

resources, communities (noise and 

traffic), water resources, wetlands, and 

ecological resources. 

Public Scoping Process: To ensure 

that all issues related to this proposal 

are properly addressed, DOE will 

conduct an open process to define the 

scope of the EIS. The public scoping 

period will end on October 23, 2008. 

Interested agencies, organizations, and 

the general public are encouraged to 

submit comments or suggestions 

concerning the content of the EIS, issues 

and impacts to be addressed in the EIS, 

and alternatives that should be 

considered. Scoping comments should 

clearly describe specific issues or topics 

that the EIS should address in order to 

assist DOE in identifying significant 

issues. Written, e-mailed, faxed, or 

telephoned comments should be 

communicated by October 23, 2008 (see 

ADDRESSES). 

In addition, DOE will conduct a 

public scoping meeting at the Kemper 

County High School, 429 Philadelphia 

Road, DeKalb, Mississippi, at 7 PM on 

October 14, 2008. The public is also 

invited to learn more about the 

proposed project at an informal session 

at this location beginning at 5 PM. DOE 

requests that anyone who wishes to 

speak at this public scoping meeting 

contact Mr. Richard A. Hargis, either by 

phone, fax, computer, or in writing (see 

ADDRESSES). 

Individuals who do not make advance 

arrangements to speak may register at 

the meeting and will be given the 

opportunity to speak following 

previously scheduled speakers. 

Speakers who need more than five 

minutes should indicate the length of 

time desired in their request. Depending 

on the number of speakers, DOE may 

need to limit speakers to five-minute 

presentations initially, but will provide 

additional opportunities as time 

permits. Speakers can also provide 

written material to supplement their 

presentations. Oral and written 

comments will be given equal weight. 

DOE will begin the formal meeting 

with an overview of the proposed 

Kemper County IGCC Project. DOE will 

designate a presiding officer to chair the 

meeting. The meeting will not be 

conducted as an evidentiary hearing, 

and speakers will not be crossexamined. However, speakers may be 

asked questions to ensure that DOE fully 

understands their comments or 

suggestions. The presiding officer will 

establish the order of speakers and 

provide any additional procedures 

necessary to conduct the meeting. 

Issued in Washington, DC, this 17th day of 

September 2008. 

James A. Slutz, 

Assistant Secretary (Acting), Office of Fossil 

Energy. 

[FR Doc. E8–22100 Filed 9–19–08; 8:45 am] 

BILLING CODE 6450–01–P 

DEPARTMENT OF ENERGY 

Notice of Interim Approval 

AGENCY: Southeastern Power 

Administration, DOE. 

ACTION: Notice of Interim Approval for 

Southeastern Power Administration 

Cumberland System. 

SUMMARY: The Deputy Secretary of 

Energy confirmed and approved, on an 

interim basis, Rate Schedules CBR–1–G, 

CSI–1–G, CEK–1–G, CM–1–G, CC–1–H, 

CK–1–G, CTV–1–G, and Replacement-3. 

The rates were approved on an interim 

basis through September 30, 2013. The 

new rates take effect on October 1, 2008, 

and are subject to confirmation and 

approval on a final basis by the Federal 

Energy Regulatory Commission 

(‘‘FERC’’). 

DATES: Approval of the rate schedules 

on an interim basis is effective October 

1, 2008, through September 30, 2013. 

FOR FURTHER INFORMATION CONTACT: 

Leon Jourolmon, Assistant 


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54574 Federal Register / Vol. 73, No. 184 / Monday, September 22, 2008 / Notices 

Administrator, Finance & Marketing, 

Southeastern Power Administration, 

Department of Energy, 1166 Athens 

Tech Road, Elberton, Georgia 30635– 

6711, (706) 213–3800. 

SUPPLEMENTARY INFORMATION: On August 

19, 2008, FERC confirmed and approved 

Interim Wholesale Power Rate 

Schedules CBR–1–F, CSI–1–F, CEK–1– 

F, CM–1–F, CC–1–G, CK–1–F, and 

CTV–1–F for the period from February 

25, 2008 to September 30, 2008. 

Dated: September 12, 2008. 

Jeffrey F. Kupfer, 

Acting Deputy Secretary. 

DEPARTMENT OF ENERGY DEPUTY 

SECRETARY 

In the Matter of: Southeastern Power 

Administration 

Cumberland System Rates 

[Rate Order No. SEPA–50] 

Order Confirming and Approving 

Power Rates on an Interim Basis 

Pursuant to Sections 302(a) and 

301(b) of the Department of Energy 

Organization Act, Public Law 95–91, the 

functions of the Secretary of the Interior 

and the Federal Power Commission 

under Section 5 of the Flood Control 

Act of 1944, 16 U.S.C. 825s, relating to 

the Southeastern Power Administration 

(‘‘Southeastern’’ or ‘‘SEPA’’) were 

transferred to and vested in the 

Secretary of Energy. By Delegation 

Order No. 00–037.00, effective 

December 6, 2001, the Secretary of 

Energy delegated to Southeastern’s 

Administrator the authority to develop 

power and transmission rates, and 

delegated to the Deputy Secretary of 

Energy the authority to confirm, 

approve, and place in effect such rates 

on an interim basis, and delegated to the 

Federal Energy Regulatory Commission 

(‘‘FERC’’) the authority to confirm, 

approve, and place into effect on a final 

basis or to disapprove rates developed 

by the Administrator under the 

delegation. This rate order is issued by 

the Deputy Secretary pursuant to said 

notice. 

Background 

The FERC issued an order approving 

Rate Schedules CBR–1–F, CSI–1–F, 

CEK–1–F, CM–1–F, CC–1–G, CK–1–F, 

and CTV–1–F on a final basis for the 

sale of power from the Cumberland 

System August 19, 2008 (124 FERC 

¶ 62,139). 

The power marketing policy provides 

peaking capacity, along with 1500 hours 

of energy with each kilowatt of capacity, 

to customers outside the Tennessee 

Valley Authority (‘‘TVA’’) transmission 

system. Due to restrictions on the 

operations of the Wolf Creek and Center 

Hill Projects imposed by the U.S. Army 

Corps of Engineers (‘‘Corps’’) as a 

precaution to prevent failure of the dam, 

Southeastern has not been able to 

provide peaking capacity to these 

customers. An interim operating plan 

for the Cumberland System provides 

these customers with energy that does 

not include capacity. 

Public Notice and Comment 

Notice of a proposed rate adjustment 

was published in the Federal Register 

April 11, 2008 (73 FR 19832). The 

notice advised interested parties of a 

public information and comment forum 

to be held in Nashville, Tennessee on 

May 22, 2008. Written comments were 

accepted on or before July 10, 2008. 

Written comments were received from 

six sources pursuant to this notice. 

Comment 1: There is concern * * * 

whether the amounts included for Corps 

Operation and Maintenance (‘‘O&M’’) 

expense are appropriate forecasts in 

light of potential budget cuts in Corps 

appropriations in Fiscal Year 2009. 

The Southeastern Federal Power 

Customers, Inc. (‘‘SeFPC’’ or 

‘‘Customers’’) has frequently questioned 

whether the amounts for Corps O&M 

and at times renewals and replacements, 

in a proposed rate are appropriate when 

Congress appears poised to reduce the 

funding levels for these precise 

activities. In particular, the Customers 

have not wanted to pay more in rates 

than what the Corps will receive from 

Congress for O&M and renewals and 

replacement activity. Therefore, the 

Customers encourage SEPA to examine 

closely the proposed O&M projections 

to ensure that they appropriately align 

with anticipated appropriations. 

Response 1: The Corps provides O&M 

estimates to Southeastern annually. The 

customers have an opportunity to 

review the Corps’ estimated and actual 

costs annually through the O&M 

committee of the SeFPC. Southeastern 

believes that the estimates are the best 

available. 

Comment 2: * * * the SeFPC suggests 

that SEPA develop a consultation and 

related true-up process for 

implementing a rate in the event that 

capacity is made available. Under the 

consultation and true-up process 

suggested * * * SEPA would consult 

with preference customers regarding 

available capacity to market to all 

existing customers of the Cumberland 

River Basin projects. The consultation 

could involve a meeting or conference 

call or some other communication 

depending upon the immediacy of the 

available capacity. During this 

conference with the customers, SEPA 

would explain how it intends to market 

the capacity and how it would recover 

the necessary revenues. At or around 

this time, the customers could suggest 

how the marketing of the capacity could 

be adjusted, including offering 

comments as suitable on the appropriate 

pricing for capacity and energy. SEPA 

would consider the input from the 

customers and make modifications as 

deemed appropriate for the 

implementation of the interim rate for 

capacity and energy sales. 

To remain true to the proposed rate, 

the Customers recommend that SEPA 

evaluate the sales of capacity and energy 

on an ongoing, yet practical, basis to 

determine whether the capacity and 

energy delivered was consistent with 

the projections used to develop the rates 

under rate Alternative Two. In the event 

that there is a significant deviation in 

the amount of delivered capacity and 

energy from the projections used to 

prepare the rate, SEPA would again 

consult with the customers. As 

appropriate, SEPA would change the 

interim rate for the capacity and energy 

sales to ensure that the delivery of the 

benefits of the projects remains 

consistent with the underlying 

marketing plan for the Cumberland 

System of Projects. 

Response 2: Southeastern will consult 

with Cumberland System customers on 

any marketing arrangements and rate 

design matters involved in the rates 

under Alternative Two. The 

consultation could include meetings, 

conference calls, or some other 

communications depending on the 

immediacy of the available capacity. 

Southeastern will consider the input 

from the customers and make 

modifications Southeastern deems 

appropriate for the implementation of 

the interim rate for capacity and energy 

sales. 

Southeastern does not believe a trueup mechanism is appropriate or 

necessary for the rates that may be 

established under Alternative Two. 

Southeastern evaluates and monitors all 

sales of capacity and energy on an 

ongoing, continuous basis and makes 

changes when Southeastern determines 

they are appropriate. 

Comment 3: South Mississippi 

Electric Power Association (‘‘SMEPA’’) 

encourages SEPA to examine closely the 

proposed rate increase and keep it to the 

absolute minimum required to satisfy 

SEPA revenue requirements. 

Response 3: Under the Flood Control 

Act of 1944 (‘‘Act’’), Southeastern is 

required to market power at the lowest 

possible rates consistent with sound 

business principles. The Administrator 


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has certified that the proposed rates 

satisfy this requirement of the Act. 

Comment 4: East Kentucky Power 

Cooperative (‘‘EKPC’’) submits that 

SEPA is not purchasing firm 

transmission service for the 70 MW at 

the Laurel Dam facility; therefore, EKPC 

should not have to pay a firm TVA 

transmission service charge for that 

capacity. 

Response 4: By contract, under 

normal operating conditions, EKPC will 

receive 170 MW from the Cumberland 

projects. Delivery of EKPC’s allocation 

is not limited to the operations of any 

Cumberland project. The output of the 

Laurel Project, which is in EKPC’s 

control area, is supplemented by energy 

and capacity from the Cumberland 

Projects in TVA’s control area. 

Southeastern believes it is appropriate 

to continue to recover the TVA 

transmission charge from EKPC’s full 

allocation. 

Comment 5: It is TVA’s understanding 

that there were certain errors in the 

financial information set forth in Exhibit 

5 of SEPA’s rate change support 

materials. Those errors in turn resulted 

in errors in the calculation of the 

published proposed rate changes for 

TVA and for SEPA’s other Cumberland 

System customers. It is TVA’s 

understanding that SEPA is aware of 

those errors and intends to correct them. 

Accordingly, TVA’s forbearance of 

raising objections to the proposed rate 

changes is based on TVA’s expectation 

that these corrections will be made such 

that the new rates to be paid by all 

SEPA’s Cumberland System customers 

will be increased by approximately the 

same 4.9 per centum consistent with 

SEPA’s own policies for such rate 

changes regarding the Cumberland 

System of Projects. 

Response 5: Southeastern has 

corrected certain errors in the rate 

design of the proposed rates under 

Alternative Three. After correcting the 

errors, the rate adjustment is about five 

percent (5%) for all Cumberland 

customers except those in Carolina 

Power & Light, Western Division 

(‘‘CP&L’’). The CP&L area customers’ 

increase is less because the CP&L 

transmission rate has not changed. 

Comment 6: The purpose for the 

proposed rate changes cannot be 

achieved unless the Corps, SEPA, and 

the Cumberland System customers 

reach agreement upon and implement 

Memorandums of Agreement (‘‘MOAs’’) 

sufficient to cover each and all of Fiscal 

Years 2008 through 2028 and related 

Sub-agreements. Accordingly, TVA’s 

forbearance of raising objections to the 

proposed rate changes is based on 

TVA’s expectation that MOAs and 

related Sub-agreements * * * will be 

executed and appropriately 

implemented. 

The Tennessee Valley Public Power 

Association (‘‘TVPPA’’) respectfully 

recommends that unless and until the 

United States Army Corps of Engineers 

(‘‘USACE’’), the Southeastern Power 

Administration (‘‘SEPA’’) and the 

Cumberland System Customers of SEPA 

have reached an agreement with a 

specific understanding as to amount and 

duration for rehabilitation and 

replacement work on the USACE 

hydroelectric projects on the 

Cumberland System, that the rate 

increase should not be implemented. 

Response 6: Southeastern is required 

to include estimates of replacements 

and additions in the repayment study to 

support the proposed rate schedules. 

Southeastern believes the estimates of 

replacements and additions included in 

this rate adjustment are the best 

available. Southeastern believes this rate 

adjustment would be necessary 

independent of the implementation of 

MOAs and related Sub-agreements. 

Discussion 

System Repayment 

An examination of Southeastern’s 

revised system power repayment study, 

prepared in July 2008, for the 

Cumberland System, shows that with 

the proposed rates, all system power 

costs are paid within the 50-year 

repayment period required by existing 

law and DOE Order RA 6120.2. The 

Administrator of Southeastern has 

certified that the rates are consistent 

with applicable law and that they are 

the lowest possible rates to customers 

consistent with sound business 

principles. 

Environmental Impact 

Southeastern has reviewed the 

possible environmental impacts of the 

rate adjustment under consideration and 

has concluded that, because the 

adjusted rates would not significantly 

affect the quality of the human 

environment within the meaning of the 

National Environmental Policy Act of 

1969, the proposed action is not a major 

Federal action for which preparation of 

an Environmental Impact Statement is 

required. 

Availability of Information 

Information regarding these rates, 

including studies, and other supporting 

materials, is available for public review 

in the offices of Southeastern Power 

Administration, 1166 Athens Tech 

Road, Elberton, Georgia 30635–6711. 

Submission to the Federal Energy 

Regulatory Commission 

The rates hereinafter confirmed and 

approved on an interim basis, together 

with supporting documents, will be 

submitted promptly to FERC for 

confirmation and approval on a final 

basis, ending no later than September 

30, 2013. 

Order 

In view of the foregoing and pursuant 

to the authority delegated to me by the 

Secretary of Energy, I hereby confirm 

and approve on an interim basis, 

effective October 1, 2008, attached 

Wholesale Power Rate Schedules CBR– 

1–G, CSI–1–G, CEK–1–G, CM–1–G, CC– 

1–H, CK–1–G, CTV–1–G, and 

Replacement–3. The rate schedules 

shall remain in effect on an interim 

basis through September 30, 2013, 

unless such period is extended or until 

FERC confirms and approves them or 

substitute rate schedules on a final 

basis. 

Dated: September 12, 2008. 

Jeffrey F. Kupfer, 

Acting Deputy Secretary. 

Wholesale Power Rate Schedule 

CBR–1–G 

Availability 

This rate schedule shall be available 

to Big Rivers Electric Corporation and 

includes the City of Henderson, 

Kentucky, (hereinafter called the 

Customer). 

Applicability 

This rate schedule shall be applicable 

to electric capacity and energy available 

from the Dale Hollow, Center Hill, Wolf 

Creek, Cheatham, Old Hickory, Barkley, 

J. Percy Priest and Cordell Hull Projects 

(all of such projects being hereinafter 

called collectively the ‘‘Cumberland 

Projects’’) and sold in wholesale 

quantities. 

Character of Service 

The electric capacity and energy 

supplied hereunder will be three-phase 

alternating current at a nominal 

frequency of sixty hertz. The power 

shall be delivered at nominal voltages of 

13,800 volts and 161,000 volts to the 

transmission system of Big Rivers 

Electric Corporation. 

Points of Delivery 

Capacity and energy delivered to the 

Customer will be delivered at points of 

interconnection of the Customer at the 

Barkley Project Switchyard, at a 

delivery point in the vicinity of the 

Paradise steam plant and at such other 

points of delivery as may hereafter be 


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agreed upon by the Government and 

TVA. 

Billing Month 

The billing month for power sold 

under this schedule shall end at 2400 

hours CDT or CST, whichever is 

currently effective, on the last day of 

each calendar month. 

Conditions of Service 

The customer shall at its own expense 

provide, install, and maintain on its side 

of each delivery point the equipment 

necessary to protect and control its own 

system. In so doing, the installation, 

adjustment, and setting of all such 

control and protective equipment at or 

near the point of delivery shall be 

coordinated with that which is installed 

by and at the expense of TVA on its side 

of the delivery point. 

Southeastern is including three rate 

alternatives. All of the rate alternatives 

have a revenue requirement of 

$50,400,000. 

Rate Alternative 1—Interim Operating 

Plan 

The final marketing policy for the 

Cumberland System was published in 

the Federal Register August 5, 1993 (58 

FR 41762). The marketing policy for the 

Cumberland System of Projects provides 

peaking capacity, along with 1500 hours 

of energy annually with each kilowatt of 

capacity, to customers outside the 

Tennessee Valley Authority (TVA) 

transmission system. Due to restrictions 

on the operation of the Wolf Creek 

Project and the Center Hill Project 

imposed by the U.S. Army Corps of 

Engineers as a precaution to prevent 

failure of the dams, Southeastern is not 

able to provide peaking capacity to 

these customers. Southeastern 

implemented an Interim Operating Plan 

for the Cumberland System to provide 

these customers with energy that did 

not include capacity. The rates under 

Alternative 1 will remain in effect for 

the duration of the Interim Operating 

Plan. 

Monthly Rate 

The monthly rate for capacity and 

energy sold under this rate schedule 

shall be: 

Demand Charge 

None. 

Energy Charge 

12.67 mills per kilowatt-hour. 

Transmission 

The Customer will pay a ratable 

percent listed below of the credit the 

Administrator of Southeastern Power 

Administration (Administrator) 

provides to the Tennessee Valley 

Authority (TVA) as consideration for 

delivering capacity and energy for the 

account of the Administrator to points 

of delivery of Other Customers or 

interconnection points of delivery with 

other electric systems for the benefit of 

Other Customers, as agreed by contract 

between the Administrator and TVA. 

Big Rivers Electric Corporation— 

32.660% 

City of Henderson, Kentucky—2.202% 

Energy To Be Furnished by the 

Government 

The Customer will receive a ratable 

share of the energy made available by 

the Nashville District of the U.S. Army 

Corps of Engineers. 

Rate Alternative 2—Cost Recovered 

From Capacity and Energy 

This rate alternative will be 

implemented if a portion of the 

Cumberland Capacity can be scheduled, 

though not all the capacity in the 

published marketing policy can be 

scheduled. The revenue requirement 

under this alternative is $50,400,000, 

the same as the revenue requirement in 

Alternatives 1 and 3. The rate 

alternative 2 will receive revenues from 

capacity that can be scheduled and the 

remainder from energy, at charges that 

will be determined at the time. Under 

alternative 2, the cost of the TVA 

transmission credit will be passed to 

customers outside the TVA System. 

This rate alternative will be in effect 

when the Corps modifies operation of 

the Wolf Creek Project and the Center 

Hill Project to allow some of the 

capacity scheduled. When the lake level 

rises and capacity is available, the 

capacity will be allocated on an interim 

basis to the customers. 

Rate Alternative 3—Original 

Cumberland Marketing Policy 

The third rate alternative will go into 

effect once the Corps lifts all restrictions 

on the operation of the Wolf Creek Dam 

and Center Hill Dam and Southeastern 

returns to operations that support the 

published marketing policy. 

Monthly Rate 

The monthly rate for capacity and 

energy sold under this rate schedule 

shall be: 

Demand Charge 

$3.538 per kilowatt/month of total 

contract demand. 

Energy Charge 

None. 

Energy To Be Furnished by the 

Government 

The Government shall make available 

each contract year to the customer from 

the Projects through the customer’s 

interconnections with TVA and the 

customer will schedule and accept an 

allocation of 1500 kilowatt-hours of 

energy delivered at the TVA border for 

each kilowatt of contract demand. A 

contract year is defined as the 12 

months beginning July 1 and ending at 

midnight June 30 of the following 

calendar year. The energy made 

available for a contract year shall be 

scheduled monthly such that the 

maximum amount scheduled in any 

month shall not exceed 240 hours per 

kilowatt of the customer’s contract 

demand and the minimum amount 

scheduled in any month shall not be 

less than 60 hours per kilowatt of the 

customer’s contract demand. The 

customer may request and the 

Government may approve energy 

scheduled for a month greater than 240 

hours per kilowatt of the customer’s 

contract demand; provided, that the 

combined schedule of all SEPA 

customers outside TVA and served by 

TVA does not exceed 240 hours per 

kilowatt of the total contract demands of 

these customers. 

Service Interruption 

When delivery of capacity is 

interrupted or reduced due to 

conditions on the Administrator’s 

system beyond his control, the 

Administrator will continue to make 

available the portion of his declaration 

of energy that can be generated with the 

capacity available. 

For such interruption or reduction 

due to conditions on the 

Administrator’s system which have not 

been arranged for and agreed to in 

advance, the demand charge for 

capacity made available will be reduced 

as to the kilowatts of such capacity 

which have been interrupted or reduced 

in accordance with the following 

formula: 


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Number of kilowatts unavailable for at least 12 hours in any calendar day Monthly Capacity Charge

Number of Days i ( )×n Billing Month





 





Wholesale Power Rate Schedule 

CSI–1–G 

Availability 

This rate schedule shall be available 

to Southern Illinois Power Cooperative 

(hereinafter the Customer). 

Applicability 

This rate schedule shall be applicable 

to electric capacity and energy available 

from the Dale Hollow, Center Hill, Wolf 

Creek, Cheatham, Old Hickory, Barkley, 

J. Percy Priest and Cordell Hull Projects 

(all of such projects being hereinafter 

called collectively the ‘‘Cumberland 

Projects’’) and sold in wholesale 

quantities. 

Character of Service 

The electric capacity and energy 

supplied hereunder will be three-phase 

alternating current at a nominal 

frequency of sixty hertz. The power 

shall be delivered at nominal voltages of 

13,800 volts and 161,000 volts to the 

transmission system of Big Rivers 

Electric Corporation. 

Points of Delivery 

Capacity and energy delivered to the 

Customer will be delivered at points of 

interconnection of the Customer at the 

Barkley Project Switchyard, at a 

delivery point in the vicinity of the 

Paradise steam plant and at such other 

points of delivery as may hereafter be 

agreed upon by the Government and 

TVA. 

Billing Month 

The billing month for power sold 

under this schedule shall end at 2400 

hours CDT or CST, whichever is 

currently effective, on the last day of 

each calendar month. 

Southeastern is including three rate 

alternatives. All of the rate alternatives 

have a revenue requirement of 

$50,400,000. 

Rate Alternative 1—Interim Operating 

Plan 

The final marketing policy for the 

Cumberland System was published in 

the Federal Register August 5, 1993 (58 

FR 41762). The marketing policy for the 

Cumberland System of Projects provides 

peaking capacity, along with 1500 hours 

of energy annually with each kilowatt of 

capacity, to customers outside the 

Tennessee Valley Authority (TVA) 

transmission system. Due to restrictions 

on the operation of the Wolf Creek 

Project and the Center Hill Project 

imposed by the U.S. Army Corps of 

Engineers as a precaution to prevent 

failure of the dams, Southeastern is not 

able to provide peaking capacity to 

these customers. Southeastern 

implemented an Interim Operating Plan 

for the Cumberland System to provide 

these customers with energy that did 

not include capacity. The rates under 

Alternative 1 will remain in effect for 

the duration of the Interim Operating 

Plan. 

Monthly Rate 

The monthly rate for capacity and 

energy sold under this rate schedule 

shall be: 

Demand Charge 

None. 

Energy Charge 

12.67 mills per kilowatt-hour. 

Transmission Charge 

The Customer will pay 5.138 percent 

of the credit the Administrator of 

Southeastern Power Administration 

(Administrator) provides to the 

Tennessee Valley Authority (TVA) as 

consideration for delivering capacity 

and energy for the account of the 

Administrator to points of delivery of 

Other Customers or interconnection 

points of delivery with other electric 

systems for the benefit of Other 

Customers, as agreed by contract 

between the Administrator and TVA. 

Energy To Be Furnished by the 

Government 

The Customer will receive a ratable 

share of the energy made available by 

the Nashville District of the U.S. Army 

Corps of Engineers. 

Rate Alternative 2—Cost Recovered 

From Capacity and Energy 

This rate alternative will be 

implemented if a portion of the 

Cumberland Capacity can be scheduled, 

though not all the capacity in the 

published marketing policy can be 

scheduled. The revenue requirement 

under this alternative is $50,400,000, 

the same as the revenue requirement in 

Alternatives 1 and 3. The rate 

alternative 2 will receive revenues from 

capacity that can be scheduled and the 

remainder from energy, at charges that 

will be determined at the time. Under 

alternative 2, the cost of the TVA 

transmission credit will be passed to 

customers outside the TVA System. 

This rate alternative will be in effect 

when the Corps modifies operation of 

the Wolf Creek Project and the Center 

Hill Project to allow some of the 

capacity scheduled. When the lake level 

rises and capacity is available, the 

capacity will be allocated on an interim 

basis to the customers. 

Rate Alternative 3—Original 

Cumberland Marketing Policy 

The third rate alternative will go into 

effect once the Corps lifts all restrictions 

on the operation of the Wolf Creek Dam 

and Center Hill Dam and Southeastern 

returns to operations that support the 

published marketing policy. 

Monthly Rate 

The monthly rate for capacity and 

energy sold under this rate schedule 

shall be: 

Demand Charge 

$3.538 per kilowatt/month of total 

contract demand. 

Energy Charge 

None. 

Energy To Be Furnished by the 

Government 

The Government shall make available 

each contract year to the customer from 

the Projects through the customer’s 

interconnections with TVA and the 

customer will schedule and accept an 

allocation of 1500 kilowatt-hours of 

energy delivered at the TVA border for 

each kilowatt of contract demand. A 

contract year is defined as the 12 

months beginning July 1 and ending at 

midnight June 30 of the following 

calendar year. The energy made 

available for a contract year shall be 

scheduled monthly such that the 

maximum amount scheduled in any 

month shall not exceed 240 hours per 

kilowatt of the customer’s contract 

demand and the minimum amount 

scheduled in any month shall not be 

less than 60 hours per kilowatt of the 

customer’s contract demand. The 

customer may request and the 

Government may approve energy 

scheduled for a month greater than 240 

hours per kilowatt of the customer’s 

contract demand; provided, that the 

combined schedule of all SEPA 

customers outside TVA and served by 

TVA does not exceed 240 hours per 

kilowatt of the total contract demands of 

these customers. 


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54578 Federal Register / Vol. 73, No. 184 / Monday, September 22, 2008 / Notices 

Service Interruption 

When delivery of capacity is 

interrupted or reduced due to 

conditions on the Administrator’s 

system beyond his control, the 

Administrator will continue to make 

available the portion of his declaration 

of energy that can be generated with the 

capacity available. 

For such interruption or reduction 

due to conditions on the 

Administrator’s system which have not 

been arranged for and agreed to in 

advance, the demand charge for 

capacity made available will be reduced 

as to the kilowatts of such capacity 

which have been interrupted or reduced 

in accordance with the following 

formula: 

Number of kilowatts unavailable for at least 12 hours in any calendar day Monthly Capacity Charge

Number of Days i ( )×n Billing Month





 





Wholesale Power Rate Schedule 

CEK–1–G 

Availability 

This rate schedule shall be available 

to East Kentucky Power Cooperative 

(hereinafter called the Customer). 

Applicability 

This rate schedule shall be applicable 

to electric capacity and energy available 

from the Dale Hollow, Center Hill, Wolf 

Creek, Cheatham, Old Hickory, Barkley, 

J. Percy Priest and Cordell Hull Projects 

(all of such projects being hereinafter 

called collectively the ‘‘Cumberland 

Projects’’) and power available from the 

Laurel Project and sold in wholesale 

quantities. 

Character of Service 

The electric capacity and energy 

supplied hereunder will be three-phase 

alternating current at a nominal 

frequency of sixty hertz. The power 

shall be delivered at nominal voltages of 

161,000 volts to the transmission 

systems of the Customer. 

Points of Delivery 

The points of delivery will be the 

161,000 volt bus of the Wolf Creek 

Power Plant and the 161,000 volt bus of 

the Laurel Project. Other points of 

delivery may be as agreed upon. 

Billing Month 

The billing month for power sold 

under this schedule shall end at 2400 

hours CDT or CST, whichever is 

currently effective, on the last day of 

each calendar month. 

Conditions of Service 

The customer shall at its own expense 

provide, install, and maintain on its side 

of each delivery point the equipment 

necessary to protect and control its own 

system. In so doing, the installation, 

adjustment and setting of all such 

control and protective equipment at or 

near the point of delivery shall be 

coordinated with that which is installed 

by and at the expense of TVA on its side 

of the delivery point. 

Southeastern is including three rate 

alternatives. All of the rate alternatives 

have a revenue requirement of 

$50,400,000. 

Rate Alternative 1—Interim Operating 

Plan 

The final marketing policy for the 

Cumberland System was published in 

the Federal Register August 5, 1993 (58 

FR 41762). The marketing policy for the 

Cumberland System of Projects provides 

peaking capacity, along with 1500 hours 

of energy annually with each kilowatt of 

capacity, to customers outside the 

Tennessee Valley Authority (TVA) 

transmission system. Due to restrictions 

on the operation of the Wolf Creek 

Project and the Center Hill Project 

imposed by the U. S. Army Corps of 

Engineers as a precaution to prevent 

failure of the dams, Southeastern is not 

able to provide peaking capacity to 

these customers. Southeastern 

implemented an Interim Operating Plan 

for the Cumberland System to provide 

these customers with energy that did 

not include capacity. The rates under 

Alternative 1 will remain in effect for 

the duration of the Interim Operating 

Plan. 

Monthly Rate 

The monthly rate for capacity and 

energy sold under this rate schedule 

shall be: 

Demand Charge 

None. 

Energy Charge 

12.67 mills per kilowatt-hour. 

Transmission Charge 

The Customer will pay 31.192 percent 

of the credit the Administrator of 

Southeastern Power Administration 

(Administrator) provides to the 

Tennessee Valley Authority (TVA) as 

consideration for delivering capacity 

and energy for the account of the 

Administrator to points of delivery of 

Other Customers or interconnection 

points of delivery with other electric 

systems for the benefit of Other 

Customers, as agreed by contract 

between the Administrator and TVA. 

Energy To Be Furnished by the 

Government 

The Customer will receive a ratable 

share of the energy made available by 

the Nashville District of the U.S. Army 

Corps of Engineers. 

Rate Alternative 2—Cost Recovered 

from Capacity and Energy 

This rate alternative will be 

implemented if a portion of the 

Cumberland Capacity can be scheduled, 

though not all the capacity in the 

published marketing policy can be 

scheduled. The revenue requirement 

under this alternative is $50,400,000, 

the same as the revenue requirement in 

Alternatives 1 and 3. The rate 

alternative 2 will receive revenues from 

capacity that can be scheduled and the 

remainder from energy, at charges that 

will be determined at the time. Under 

alternative 2, the cost of the TVA 

transmission credit will be passed to 

customers outside the TVA System. 

This rate alternative will be in effect 

when the Corps modifies operation of 

the Wolf Creek Project and the Center 

Hill Project to allow some of the 

capacity scheduled. When the lake level 

rises and capacity is available, the 

capacity will be allocated on an interim 

basis to the customers. 

Rate Alternative 3—Original 

Cumberland Marketing Policy 

The third rate alternative will go into 

effect once the Corps lifts all restrictions 

on the operation of the Wolf Creek Dam 

and Center Hill Dam and Southeastern 

returns to operations that support the 

published marketing policy. 

Monthly Rate 

The monthly rate for capacity and 

energy sold under this rate schedule 

shall be: 

Demand Charge 

$2.364 per kilowatt/month of total 

contract demand. 


sroberts on PROD1PC70 with NOTICESEN22SE08.001</GPH> 
Federal Register / Vol. 73, No. 184 / Monday, September 22, 2008 / Notices 54579 

Energy Charge 

9.392 mills per kilowatt-hour. 

Energy To Be Furnished by the 

Government 

The Government shall make available 

each contract year to the customer from 

the Projects through the customer’s 

interconnections with TVA and the 

customer will schedule and accept an 

allocation of 1500 kilowatt-hours of 

energy delivered at the TVA border for 

each kilowatt of contract demand plus 

369 kilowatt-hours of energy delivered 

for each kilowatt of contract demand to 

supplement energy available at the 

Laurel Project. A contract year is 

defined as the 12 months beginning July 

1 and ending at midnight June 30 of the 

following calendar year. The energy 

made available for a contract year shall 

be scheduled monthly such that the 

maximum amount scheduled in any 

month shall not exceed 240 hours per 

kilowatt of the customer’s contract 

demand and the minimum amount 

scheduled in any month shall not be 

less than 60 hours per kilowatt of the 

customer’s contract demand. The 

customer may request and the 

Government may approve energy 

scheduled for a month greater than 240 

hours per kilowatt of the customer’s 

contract demand; provided, that the 

combined schedule of all SEPA 

customers outside TVA and served by 

TVA does not exceed 240 hours per 

kilowatt of the total contract demands of 

these customers. 

Service Interruption 

When delivery of capacity is 

interrupted or reduced due to 

conditions on the Administrator’s 

system beyond his control, the 

Administrator will continue to make 

available the portion of his declaration 

of energy that can be generated with the 

capacity available. 

For such interruption or reduction 

due to conditions on the 

Administrator’s system which have not 

been arranged for and agreed to in 

advance, the demand charge for 

capacity made available will be reduced 

as to the kilowatts of such capacity 

which have been interrupted or reduced 

in accordance with the following 

formula: 

Number of kilowatts unavailable for at least 12 hours in any calendar day Monthly Capacity Charge

Number of Days i ( )×n Billing Month





 





Wholesale Power Rate Schedule 

CM–1–G 

Availability 

This rate schedule shall be available 

to the South Mississippi Electric Power 

Association, Municipal Energy Agency 

of Mississippi, and Mississippi Delta 

Energy Agency (hereinafter called the 

Customers). 

Applicability 

This rate schedule shall be applicable 

to electric capacity and energy available 

from the Dale Hollow, Center Hill, Wolf 

Creek, Cheatham, Old Hickory, Barkley, 

J. Percy Priest and Cordell Hull Projects 

(all of such projects being hereinafter 

called collectively the ‘‘Cumberland 

Projects’’) and sold in wholesale 

quantities. 

Character of Service 

The electric capacity and energy 

supplied hereunder will be three-phase 

alternating current at a nominal 

frequency of sixty hertz. The power 

shall be delivered at nominal voltages of 

161,000 volts to the transmission 

systems of Mississippi Power and Light. 

Points of Delivery 

The points of delivery will be at 

interconnection points of the Tennessee 

Valley Authority system and the 

Mississippi Power and Light system. 

Other points of delivery may be as 

agreed upon. 

Billing Month 

The billing month for power sold 

under this schedule shall end at 2400 

hours CDT or CST, whichever is 

currently effective on the last day of 

each calendar month. 

Southeastern is including three rate 

alternatives. All of the rate alternatives 

have a revenue requirement of 

$50,400,000. 

Rate Alternative 1—Interim Operating 

Plan 

The final marketing policy for the 

Cumberland System was published in 

the Federal Register August 5, 1993 (58 

FR 41762). The marketing policy for the 

Cumberland System of Projects provides 

peaking capacity, along with 1500 hours 

of energy annually with each kilowatt of 

capacity, to customers outside the 

Tennessee Valley Authority (TVA) 

transmission system. Due to restrictions 

on the operation of the Wolf Creek 

Project and the Center Hill Project 

imposed by the U.S. Army Corps of 

Engineers as a precaution to prevent 

failure of the dams, Southeastern is not 

able to provide peaking capacity to 

these customers. Southeastern 

implemented an Interim Operating Plan 

for the Cumberland System to provide 

these customers with energy that did 

not include capacity. The rates under 

Alternative 1 will remain in effect for 

the duration of the Interim Operating 

Plan. 

Monthly Rate 

The monthly rate for capacity and 

energy sold under this rate schedule 

shall be: 

Demand Charge 

None. 

Energy Charge 

12.67 mills per kilowatt-hour. 

Transmission Charge 

The Customer will pay a ratable 

percent listed below of the credit the 

Administrator of Southeastern Power 

Administration (Administrator) 

provides to the Tennessee Valley 

Authority (TVA) as consideration for 

delivering capacity and energy for the 

account of the Administrator to points 

of delivery of Other Customers or 

interconnection points of delivery with 

other electric systems for the benefit of 

Other Customers, as agreed by contract 

between the Administrator and TVA. 

Mississippi Delta Energy Agency— 

2.058% 

Municipal Energy Agency of 

Mississippi—3.447% 

South Mississippi EPA—9.358% 

Energy To Be Furnished by the 

Government 

The Customer will receive a ratable 

share of the energy made available by 

the Nashville District of the U.S. Army 

Corps of Engineers. 

Rate Alternative 2—Cost Recovered 

From Capacity and Energy 

This rate alternative will be 

implemented if a portion of the 

Cumberland Capacity can be scheduled, 

though not all the capacity in the 

published marketing policy can be 

scheduled. The revenue requirement 

under this alternative is $50,400,000, 

the same as the revenue requirement in 

Alternatives 1 and 3. The rate 

alternative 2 will receive revenues from 


sroberts on PROD1PC70 with NOTICESEN22SE08.002</MATH>
54580 Federal Register / Vol. 73, No. 184 / Monday, September 22, 2008 / Notices 

capacity that can be scheduled and the 

remainder from energy, at charges that 

will be determined at the time. Under 

alternative 2, the cost of the TVA 

transmission credit will be passed to 

customers outside the TVA System. 

This rate alternative will be in effect 

when the Corps modifies operation of 

the Wolf Creek Project and the Center 

Hill Project to allow some of the 

capacity scheduled. When the lake level 

rises and capacity is available, the 

capacity will be allocated on an interim 

basis to the customers. 

Rate Alternative 3—Original 

Cumberland Marketing Policy 

The third rate alternative will go into 

effect once the Corps lifts all restrictions 

on the operation of the Wolf Creek Dam 

and Center Hill Dam and Southeastern 

returns to operations that support the 

published marketing policy. 

Monthly Rate 

The monthly rate for capacity and 

energy sold under this rate schedule 

shall be: 

Demand Charge 

$3.538 per kilowatt/month of total 

contract demand. 

Energy Charge 

None. 

Energy To Be Furnished by the 

Government 

The Government shall make available 

each contract year to the Customer from 

the Projects through the Customer’s 

interconnections with TVA and the 

Customer will schedule and accept an 

allocation of 1500 kilowatt-hours of 

energy delivered at the TVA border for 

each kilowatt of contract demand. A 

contract year is defined as the 12 

months beginning July 1 and ending at 

midnight June 30 of the following 

calendar year. The energy made 

available for a contract year shall be 

scheduled monthly such that the 

maximum amount scheduled in any 

month shall not exceed 240 hours per 

kilowatt of the Customer’s contract 

demand and the minimum amount 

scheduled in any month shall not be 

less than 60 hours per kilowatt of the 

Customer’s contract demand. The 

Customer may request and the 

Government may approve energy 

scheduled for a month greater than 240 

hours per kilowatt of the Customer’s 

contract demand; provided, that the 

combined schedule of all SEPA 

Customers outside TVA and served by 

TVA does not exceed 240 hours per 

kilowatt of the total contract demands of 

these Customers. 

In the event that any portion of the 

capacity allocated to the Customers is 

not initially delivered to the Customers 

as of the beginning of a full contract 

year, the 1500 kilowatt hours shall be 

reduced 1/12 for each month of that 

year prior to initial delivery of such 

capacity. 

Service Interruption 

When delivery of capacity is 

interrupted or reduced due to 

conditions on the Administrator’s 

system beyond his control, the 

Administrator will continue to make 

available the portion of his declaration 

of energy that can be generated with the 

capacity available. 

For such interruption or reduction 

due to conditions on the 

Administrator’s system which have not 

been arranged for and agreed to in 

advance, the demand charge for 

capacity made available will be reduced 

as to the kilowatts of such capacity 

which have been interrupted or reduced 

in accordance with the following 

formula: 

Number of kilowatts unavailable for at least 12 hours in any calendar day Monthly Capacity Charge

Number of Days i ( )×n Billing Month





 





Wholesale Power Rate Schedule 

CC–1–H 

Availability 

This rate schedule shall be available 

to public bodies and cooperatives 

served through the facilities of Carolina 

Power & Light Company, Western 

Division (hereinafter called the 

Customers). 

Applicability 

This rate schedule shall be applicable 

to electric capacity and energy available 

from the Dale Hollow, Center Hill, Wolf 

Creek, Cheatham, Old Hickory, Barkley, 

J. Percy Priest and Cordell Hull Projects 

(all of such projects being hereinafter 

called collectively the ‘‘Cumberland 

Projects’’) and sold in wholesale 

quantities. 

Character of Service 

The electric capacity and energy 

supplied hereunder will be three-phase 

alternating current at a nominal 

frequency of sixty hertz. The power 

shall be delivered at nominal voltages of 

161,000 volts to the transmission system 

of Carolina Power & Light Company, 

Western Division. 

Points of Delivery 

The points of delivery will be at 

interconnecting points of the Tennessee 

Valley Authority system and the 

Carolina Power & Light Company, 

Western Division system. Other points 

of delivery may be as agreed upon. 

Billing Month 

The billing month for power sold 

under this schedule shall end at 2400 

hours CDT or CST, whichever is 

currently effective, on the last day of 

each calendar month. 

Southeastern is including three rate 

alternatives. All of the rate alternatives 

have a revenue requirement of 

$50,400,000. 

Rate Alternative 1—Interim Operating 

Plan 

The final marketing policy for the 

Cumberland System was published in 

the Federal Register August 5, 1993 (58 

FR 41762). The marketing policy for the 

Cumberland System of Projects provides 

peaking capacity, along with 1500 hours 

of energy annually with each kilowatt of 

capacity, to customers outside the 

Tennessee Valley Authority (TVA) 

transmission system. Due to restrictions 

on the operation of the Wolf Creek 

Project and the Center Hill Project 

imposed by the U.S. Army Corps of 

Engineers as a precaution to prevent 

failure of the dams, Southeastern is not 

able to provide peaking capacity to 

these customers. Southeastern 

implemented an Interim Operating Plan 

for the Cumberland System to provide 

these customers with energy that did 

not include capacity. The rates under 

Alternative 1 will remain in effect for 

the duration of the Interim Operating 

Plan. 

Monthly Rate 

The monthly rate for capacity and 

energy sold under this rate schedule 

shall be: 

Demand Charge 

None. 

Energy Charge 

12.67 mills per kilowatt-hour. 


sroberts on PROD1PC70 with NOTICESEN22SE08.003</MATH>
Federal Register / Vol. 73, No. 184 / Monday, September 22, 2008 / Notices 54581 

TVA Transmission Charge 

The Customer will pay a ratable 

percent listed below of the credit the 

Administrator of Southeastern Power 

Administration (Administrator) 

provides to the Tennessee Valley 

Authority (TVA) as consideration for 

delivering capacity and energy for the 

account of the Administrator to points 

of delivery of Other Customers or 

interconnection points of delivery with 

other electric systems for the benefit of 

Other Customers, as agreed by contract 

between the Administrator and TVA. 

French Broad EMC—1.713% 

Haywood EMC—0.501% 

Town of Waynesville—0.355% 

CP&L Transmission Charge 

The Customer will pay a ratable 

percent listed below of the charge for 

transmission service furnished by 

Carolina Power & Light Company, 

Western Division. 

French Broad EMC—66.667% 

Haywood EMC—19.512% 

Town of Waynesville—13.821% 

Energy To Be Furnished by the 

Government 

The Government will sell to the 

customer and the customer will 

purchase from the Government energy 

each billing month equivalent to a 

percentage specified by contract of the 

energy made available to Carolina 

Power & Light Company (less applicable 

losses). The Customer’s contract 

demand and accompanying energy 

allocation will be divided pro rata 

among its individual delivery points 

served from the Carolina Power & Light 

Company’s Western Division 

transmission system. 

Rate Alternative 2—Cost Recovered 

From Capacity and Energy 

This rate alternative will be 

implemented if a portion of the 

Cumberland Capacity can be scheduled, 

though not all the capacity in the 

published marketing policy can be 

scheduled. The revenue requirement 

under this alternative is $50,400,000, 

the same as the revenue requirement in 

Alternatives 1 and 3. The rate 

alternative 2 will receive revenues from 

capacity that can be scheduled and the 

remainder from energy, at charges that 

will be determined at the time. Under 

alternative 2, the cost of the TVA 

transmission credit will be passed to 

customers outside the TVA System. 

This rate alternative will be in effect 

when the Corps modifies operation of 

the Wolf Creek Project and the Center 

Hill Project to allow some of the 

capacity scheduled. When the lake level 

rises and capacity is available, the 

capacity will be allocated on an interim 

basis to the customers. 

Rate Alternative 3—Original 

Cumberland Marketing Policy 

The third rate alternative will go into 

effect once the Corps lifts all restrictions 

on the operation of the Wolf Creek Dam 

and Center Hill Dam and Southeastern 

returns to operations that support the 

published marketing policy. 

Monthly Rate 

The monthly rate for capacity and 

energy sold under this rate schedule 

shall be: 

Demand Charge 

$4.027 per kilowatt/month of total 

contract demand. 

Energy Charge 

None. 

CP&L Transmission Charge 

$1.1022 per kilowatt/month of total 

contract demand. 

The CP&L transmission rate is subject 

to annual adjustment on April 1 of each 

year and will be computed subject to the 

formula in Appendix A attached to the 

Government-Carolina Power & Light 

Company contract. 

Energy To Be Furnished by the 

Government 

The Government will sell to the 

customer and the customer will 

purchase from the Government energy 

each billing month equivalent to a 

percentage specified by contract of the 

energy made available to Carolina 

Power & Light Company (less six 

percent (6%) losses). The Customer’s 

contract demand and accompanying 

energy allocation will be divided pro 

rata among its individual delivery 

points served from the Carolina Power 

& Light Company’s Western Division 

transmission system. 

Wholesale Power Rate Schedule 

CK–1–G 

Availability 

This rate schedule shall be available 

to public bodies served through the 

facilities of Kentucky Utilities Company 

(hereinafter called the Customers.) 

Applicability 

This rate schedule shall be applicable 

to electric capacity and energy available 

from the Dale Hollow, Center Hill, Wolf 

Creek, Cheatham, Old Hickory, Barkley, 

J. Percy Priest and Cordell Hull Projects 

(all of such projects being hereinafter 

called collectively the ‘‘Cumberland 

Projects’’) and sold in wholesale 

quantities. 

Character of Service 

The electric capacity and energy 

supplied hereunder will be three-phase 

alternating current at a nominal 

frequency of sixty hertz. The power 

shall be delivered at nominal voltages of 

161,000 volts to the transmission 

systems of Kentucky Utilities Company. 

Points of Delivery 

The points of delivery will be at 

interconnecting points between the 

Tennessee Valley Authority system and 

the Kentucky Utilities Company system. 

Other points of delivery may be as 

agreed upon. 

Billing Month 

The billing month for power sold 

under this schedule shall end at 2400 

hours CDT or CST, whichever is 

currently effective on the last day of 

each calendar month. 

Southeastern is including three rate 

alternatives. All of the rate alternatives 

have a revenue requirement of 

$50,400,000. 

Rate Alternative 1—Interim Operating 

Plan 

The final marketing policy for the 

Cumberland System was published in 

the Federal Register August 5, 1993 (58 

FR 41762). The marketing policy for the 

Cumberland System of Projects provides 

peaking capacity, along with 1500 hours 

of energy annually with each kilowatt of 

capacity, to customers outside the 

Tennessee Valley Authority (TVA) 

transmission system. Due to restrictions 

on the operation of the Wolf Creek 

Project and the Center Hill Project 

imposed by the U.S. Army Corps of 

Engineers as a precaution to prevent 

failure of the dams, Southeastern is not 

able to provide peaking capacity to 

these customers. Southeastern 

implemented an Interim Operating Plan 

for the Cumberland System to provide 

these customers with energy that did 

not include capacity. The rates under 

Alternative 1 will remain in effect for 

the duration of the Interim Operating 

Plan. 

Monthly Rate 

The monthly rate for capacity and 

energy sold under this rate schedule 

shall be: 

Demand Charge 

None. 

Energy Charge 

12.67 mills per kilowatt-hour. 


sroberts on PROD1PC70 with NOTICES
54582 Federal Register / Vol. 73, No. 184 / Monday, September 22, 2008 / Notices 

Transmission Charge 

The Customer will pay a ratable 

percent listed below of the credit the 

Administrator of Southeastern Power 

Administration (Administrator) 

provides to the Tennessee Valley 

Authority (TVA) as consideration for 

delivering capacity and energy for the 

account of the Administrator to points 

of delivery of Other Customers or 

interconnection points of delivery with 

other electric systems for the benefit of 

Other Customers, as agreed by contract 

between the Administrator and TVA. 

City of Barbourville ............. 0.404% 

City of Bardstown ................ 0.412% 

City of Bardwell ................... 0.099% 

City of Benham .................... 0.046% 

City of Corbin ...................... 0.477% 

City of Falmouth .................. 0.108% 

City of Frankfort .................. 2.866% 

City of Madisonville ............ 1.432% 

City of Nicholasville ............ 0.469% 

City of Owensboro ............... 4.587% 

City of Paris ......................... 0.250% 

City of Providence ............... 0.226% 

Energy To Be Furnished by the 

Government 

The Customer will receive a ratable 

share of the energy made available by 

the Nashville District of the U.S. Army 

Corps of Engineers. 

Rate Alternative 2—Cost Recovered 

From Capacity and Energy 

This rate alternative will be 

implemented if a portion of the 

Cumberland Capacity can be scheduled, 

though not all the capacity in the 

published marketing policy can be 

scheduled. The revenue requirement 

under this alternative is $50,400,000, 

the same as the revenue requirement in 

Alternatives 1 and 3. The rate 

alternative 2 will receive revenues from 

capacity that can be scheduled and the 

remainder from energy, at charges that 

will be determined at the time. Under 

alternative 2, the cost of the TVA 

transmission credit will be passed to 

customers outside the TVA System. 

This rate alternative will be in effect 

when the Corps modifies operation of 

the Wolf Creek Project and the Center 

Hill Project to allow some of the 

capacity scheduled. When the lake level 

rises and capacity is available, the 

capacity will be allocated on an interim 

basis to the customers. 

Rate Alternative 3—Original 

Cumberland Marketing Policy 

The third rate alternative will go into 

effect once the Corps lifts all restrictions 

on the operation of the Wolf Creek Dam 

and Center Hill Dam and Southeastern 

returns to operations that support the 

published marketing policy. 

Monthly Rate 

The monthly rate for capacity and 

energy sold under this rate schedule 

shall be: 

Demand Charge 

$3.538 per kilowatt/month of total 

contract demand 

Energy Charge 

None. 

Additional Energy Charge 

9.392 mills per kilowatt-hour. 

Energy To Be Furnished by the 

Government 

The Government shall make available 

each contract year to the Customer from 

the Projects and the Customer will 

accept an allocation of 1500 kilowatthours of energy for each kilowatt of 

contract demand. A contract year is 

defined as the 12 months beginning July 

1 and ending at midnight June 30 of the 

following calendar year. The energy 

made available for a contract year shall 

be scheduled monthly such that the 

maximum amount scheduled in any 

month shall not exceed 240 hours per 

kilowatt of the Customer’s contract 

demand and the minimum amount 

scheduled in any month shall not be 

less than 60 hours per kilowatt of the 

Customer’s contract demand. The 

Customer may request and the 

Government may approve energy 

scheduled for a month greater than 240 

hours per kilowatt of the Customer’s 

contract demand; provided, that the 

combined schedule of all SEPA 

Customers outside TVA and served by 

TVA does not exceed 240 hours per 

kilowatt of the total contract demands of 

these Customers. 

In the event that any portion of the 

capacity allocated to the Customers is 

not initially delivered to the Customers 

as of the beginning of a full contract 

year, the 1500 kilowatt hours shall be 

reduced 1⁄12 for each month of that year 

prior to initial delivery of such capacity. 

For billing purposes, each kilowatt of 

capacity will include 1500 kilowatthours energy per year. Customers will 

pay for additional energy at the 

additional energy rate. 

Wholesale Power Rate Schedule 

CTV–1–G 

Availability 

This rate schedule shall be available 

to the Tennessee Valley Authority 

(hereinafter called TVA). 

Applicability 

This rate schedule shall be applicable 

to electric capacity and energy 

generated at the Dale Hollow, Center 

Hill, Wolf Creek, Old Hickory, 

Cheatham, Barkley, J. Percy Priest, and 

Cordell Hull Projects (all of such 

projects being hereafter called 

collectively the ‘‘Cumberland Projects’’) 

and the Laurel Project sold under 

agreement between the Department of 

Energy and TVA. 

Character of Service 

The electric capacity and energy 

supplied hereunder will be three-phase 

alternating current at a frequency of 

approximately 60 Hertz at the outgoing 

terminals of the Cumberland Projects’ 

switchyards. 

Billing Month 

The billing month for capacity and 

energy sold under this schedule shall 

end at 2400 hours CDT or CST, 

whichever is currently effective, on the 

last day of each calendar month. 

Contract Year 

For purposes of this rate schedule, a 

contract year shall be as in Section 13.1 

of the Southeastern Power 

Administration—Tennessee Valley 

Authority Contract. 

Power Factor 

TVA shall take capacity and energy 

from the Department of Energy at such 

power factor as will best serve TVA’s 

system from time to time; provided, that 

TVA shall not impose a power factor of 

less than .85 lagging on the Department 

of Energy’s facilities which requires 

operation contrary to good operating 

practice or results in overload or 

impairment of such facilities. 

Southeastern is including three rate 

alternatives. All of the rate alternatives 

have a revenue requirement of 

$50,400,000. 

Rate Alternative 1—Interim Operating 

Plan 

The final marketing policy for the 

Cumberland System was published in 

the Federal Register August 5, 1993 (58 

FR 41762). The marketing policy for the 

Cumberland System of Projects provides 

peaking capacity, along with 1500 hours 

of energy annually with each kilowatt of 

capacity, to customers outside the 

Tennessee Valley Authority (TVA) 

transmission system. Due to restrictions 

on the operation of the Wolf Creek 

Project and the Center Hill Project 

imposed by the U. S. Army Corps of 

Engineers as a precaution to prevent 

failure of the dams, Southeastern is not 

able to provide peaking capacity to 

these customers. Southeastern 

implemented an Interim Operating Plan 

for the Cumberland System to provide 


sroberts on PROD1PC70 with NOTICES
Federal Register / Vol. 73, No. 184 / Monday, September 22, 2008 / Notices 54583 

these customers with energy that did 

not include capacity. The rates under 

Alternative 1 will remain in effect for 

the duration of the Interim Operating 

Plan. 

Monthly Rates 

The monthly rate for capacity and 

energy sold under this rate schedule 

shall be: 

Demand Charge 

None. 

Energy Charge 

12.67 mills per kilowatt-hour. 

Energy To Be Made Available 

The Customer will receive a ratable 

share of the energy made available by 

the Nashville District of the U.S. Army 

Corps of Engineers. 

Rate Alternative 2—Cost Recovered 

From Capacity and Energy 

This rate alternative will be 

implemented if a portion of the 

Cumberland Capacity can be scheduled, 

though not all the capacity in the 

published marketing policy can be 

scheduled. The revenue requirement 

under this alternative is $50,400,000, 

the same as the revenue requirement in 

Alternatives 1 and 3. The rate 

alternative 2 will receive revenues from 

capacity that can be scheduled and the 

remainder from energy, at charges that 

will be determined at the time. Under 

alternative 2, the cost of the TVA 

transmission credit will be passed to 

customers outside the TVA System. 

This rate alternative will be in effect 

when the Corps modifies operation of 

the Wolf Creek Project and the Center 

Hill Project to allow some of the 

capacity scheduled. When the lake level 

rises and capacity is available, the 

capacity will be allocated on an interim 

basis to the customers. 

Rate Alternative 3—Original 

Cumberland Marketing Policy 

The third rate alternative will go into 

effect once the Corps lifts all restrictions 

on the operation of the Wolf Creek Dam 

and Center Hill Dam and Southeastern 

returns to operations that support the 

published marketing policy. 

Monthly Rate 

The monthly rate for capacity and 

energy sold under this rate schedule 

shall be: 

Demand Charge 

$2.072 per kilowatt/month of total 

contract demand. 

Energy Charge 

None. 

Additional Energy Charge 

9.392 mills per kilowatt-hour. 

Energy To Be Made Available 

The Department of Energy shall 

determine the energy that is available 

from the projects for declaration in the 

billing month. 

To meet the energy requirements of 

the Department of Energy’s customers 

outside the TVA area (hereinafter called 

Other Customers), 768,000 megawatthours of net energy shall be available 

annually (including 36,900 megawatthours of annual net energy to 

supplement energy available at Laurel 

Project). The energy requirement of the 

Other Customers shall be available 

annually, divided monthly such that the 

maximum available in any month shall 

not exceed 240 hours per kilowatt of 

total Other Customers contract demand, 

and the minimum amount available in 

any month shall not be less than 60 

hours per kilowatt of total Other 

Customers demand. 

In the event that any portion of the 

capacity allocated to Other Customers is 

not initially delivered to the Other 

Customers as of the beginning of a full 

contract year, (July through June), the 

1500 hours, plus any such additional 

energy required as discussed above, 

shall be reduced 1⁄12 for each month of 

that year prior to initial delivery of such 

capacity. 

The energy scheduled by TVA for use 

within the TVA System in any billing 

month shall be the total energy 

delivered to TVA less (1) an adjustment 

for fast or slow meters, if any, (2) an 

adjustment for Barkley-Kentucky Canal 

of 15,000 megawatt-hours of energy 

each month which is delivered to TVA 

under the agreement from the 

Cumberland Projects without charge to 

TVA, (3) the energy scheduled by the 

Department of Energy in said month for 

the Other Customers plus losses of two 

(2) percent, and (4) station service 

energy furnished by TVA. 

Each kilowatt of capacity will include 

1500 kilowatt-hours of energy per year, 

which is defined as base energy. Energy 

received in excess of 1500 kilowatthours per kilowatt will be subject to an 

additional energy charge identified in 

the monthly rates section of this rate 

schedule. 

Service Interruption 

When delivery of capacity to TVA is 

interrupted or reduced due to 

conditions on the Department of 

Energy’s system that are beyond its 

control, the Department of Energy will 

continue to make available the portion 

of its declaration of energy that can be 

generated with the capacity available. 

For such interruption or reduction 

(exclusive of any restrictions provided 

in the agreement) due to conditions on 

the Department of Energy’s system 

which have not been arranged for and 

agreed to in advance, the demand 

charge for scheduled capacity made 

available to TVA will be reduced as to 

the kilowatts of such scheduled capacity 

which have been so interrupted or 

reduced for each day in accordance with 

the following formula: 

Number of kilowatts unavailable for

at least 12 hours in any calendar day

Monthly Capacity Charge

Number of Days i ( )×

n Billing Month

Contract Demand

 Kilowatts





 



×



 880 000 ,







Wholesale Rate Schedule 

Replacement—3 

Availability 

This rate schedule shall be available 

to public bodies and cooperatives ( any 

one of whom is hereinafter called the 

Customer) in Virginia, North Carolina, 

Tennessee, Georgia, Alabama, 

Mississippi, Kentucky and southern 

Illinois to whom power is provided 

pursuant to contracts between the 

Government and the customer from the 

Dale Hollow, Center Hill, Wolf Creek, 

Cheatham, Old Hickory, Barkley, J. 

Percy Priest, Cordell Hull, and Laurel 

Projects (all of such projects being 

hereinafter called collectively the 

‘‘Cumberland Projects’’). 

Applicability 

This rate schedule shall be applicable 

to the sale of wholesale energy 

purchased to meet contract minimum 

energy sold under appropriate contracts 

between the Government and the 

Customer. 


sroberts on PROD1PC70 with NOTICESEN22SE08.004</MATH> 
54584 Federal Register / Vol. 73, No. 184 / Monday, September 22, 2008 / Notices 

Character of Service 

The energy supplied hereunder will 

be delivered at the delivery points 

provided for under appropriate 

contracts between the Government and 

the Customer. 

Monthly Charge 

The rate for replacement energy will 

be a formulary capacity charge based on 

the monthly cost to the Government to 

purchase replacement energy necessary 

to support capacity in the Cumberland 

System divided by the capacity 

available from the Cumberland System, 

which is 950,000 kilowatts in the 

published power marketing policy. The 

capacity rate will be adjusted for any 

capacity retained by the Customer’s 

transmission facilitator. 

Conditions of Service 

The customer shall at its own expense 

provide, install, and maintain on its side 

of each delivery point the equipment 

necessary to protect and control its own 

system. 

[FR Doc. E8–22097 Filed 9–19–08; 8:45 am] 

BILLING CODE 6450–01–P 

DEPARTMENT OF ENERGY 

Energy Information Administration 

Agency Information Collection 

Activities: Submission for OMB 

Review; Comment Request 

AGENCY: Energy Information 

Administration (EIA), Department of 

Energy (DOE). 

ACTION: Agency Information Collection 

Activities: Submission for OMB Review; 

Comment Request. 

SUMMARY: The EIA has submitted the 

Petroleum Supply Reporting System 

package to the Office of Management 

and Budget (OMB) for review and a 

three-year extension under section 

3507(h)(1) of the Paperwork Reduction 

Act of 1995 (Pub. L. 104–13) (44 U.S.C. 

3501 et seq). 

DATES: Comments must be filed by 

October 22, 2008. If you anticipate that 

you will be submitting comments but 

find it difficult to do so within that 

period, you should contact the OMB 

Desk Officer for DOE listed below as 

soon as possible. 

ADDRESSES: Send comments to OMB 

Desk Officer for DOE, Office of 

Information and Regulatory Affairs, 

Office of Management and Budget. To 

ensure receipt of the comments by the 

due date, submission by FAX at 202– 

395–7285 or e-mail to 

Nathan_J._Frey@omb.eop.gov is 

recommended. The mailing address is 

726 Jackson Place, NW., Washington, 

DC 20503. The OMB DOE Desk Officer 

may be telephoned at (202) 395–7345. 

(A copy of your comments should also 

be provided to EIA’s Statistics and 

Methods Group at the address below.) 

FOR FURTHER INFORMATION CONTACT: 

Requests for additional information 

should be directed to Grace Sutherland. 

To ensure receipt of the comments by 

the due date, submission by FAX (202– 

586–5271) or e-mail 

(grace.sutherland@eia.doe.gov) is also 

recommended. The mailing address is 

Statistics and Methods Group (EI–70), 

Forrestal Building, U.S. Department of 

Energy, Washington, DC 20585–0670. 

Ms. Sutherland may be contacted by 

telephone at (202) 586–6264. 

SUPPLEMENTARY INFORMATION: This 

section contains the following 

information about the energy 

information collection submitted to 

OMB for review: (1) The collection 

numbers and title; (2) the sponsor (i.e., 

the Department of Energy component); 

(3) the current OMB docket number (if 

applicable); (4) the type of request (i.e., 

new, revision, extension, or 

reinstatement); (5) response obligation 

(i.e., mandatory, voluntary, or required 

to obtain or retain benefits); (6) a 

description of the need for and 

proposed use of the information; (7) a 

categorical description of the likely 

respondents; and (8) an estimate of the 

total annual reporting burden (i.e., the 

estimated number of likely respondents 

times the proposed frequency of 

response per year times the average 

hours per response). 

1. Forms EIA–800, 801, 802, 803, 804, 

805, 810, 811, 812, 813, 814, 815, 816, 

817, 819, 820 ‘‘Petroleum Supply 

Reporting System’’. 

2. Energy Information Administration. 

3. OMB Number 1905–0165. 

4. Three-year extension. 

5. Mandatory. 

6. EIA’s Petroleum Supply Reporting 

System collects information needed for 

determining the supply and disposition 

of crude oil, petroleum products, and 

natural gas liquids. The data are 

published by EIA and are used by 

public and private analysts. 

Respondents are operators of petroleum 

refineries, blending plants, bulk 

terminals, crude oil and product 

pipelines, natural gas plant facilities, 

tankers, barges, and oil importers. 

7. Business or other for-profit. 

8. 100,186 hours. 

Please refer to the supporting 

statement as well as the proposed forms 

and instructions for more information 

about the purpose, who must report, 

when to report, where to submit, the 

elements to be reported, detailed 

instructions, provisions for 

confidentiality, and uses (including 

possible nonstatistical uses) of the 

information. For instructions on 

obtaining materials, see the FOR FURTHER

INFORMATION CONTACT section. 

Statutory Authority: Section 3507(h)(1) of 

the Paperwork Reduction Act of 1995 (Pub. 

L. No. 104–13, 44 U.S.C. Chapter 35). 

Issued in Washington, DC, September 16, 

2008. 

Stephanie Brown, 

Director, Statistics and Methods Group, 

Energy Information Administration. 

[FR Doc. E8–22092 Filed 9–19–08; 8:45 am] 

BILLING CODE 6450–01–P 

DEPARTMENT OF ENERGY 

Federal Energy Regulatory 

Commission 

Combined Notice of Filings 

September 16, 2008. 

Take notice that the Commission has 

received the following Natural Gas 

Pipeline Rate and Refund Report filings: 

Docket Numbers: RP97–81–051. 

Applicants: Kinder Morgan Interstate 

Gas Transmission LLC. 

Description: Kinder Morgan Interstate 

Gas Transmission LLC submits Sixth 

Revised Sheet 4G.02 et al. to FERC Gas 

Tariff, Fourth Revised Volume 1–A. 

Filed Date: 09/12/2008. 

Accession Number: 20080916–0028. 

Comment Date: 5 p.m. Eastern Time 

on Wednesday, September 24, 2008. 

Docket Numbers: RP98–18–034. 

Applicants: Iroquois Gas 

Transmission System, L.P. 

Description: Iroquois Gas 

Transmission System, LP submits 

Original Sheet 6P et al. to FERC Gas 

Tariff, First Revised Volume 1, to be 

effective 11/1/08. 

Filed Date: 08/29/2008. 

Accession Number: 20080903–0040. 

Comment Date: 5 p.m. Eastern Time 

on Friday, September 19, 2008. 

Docket Numbers: RP99–176–165. 

Applicants: Natural Gas Pipeline 

Company of America. 

Description: Natural Gas Pipeline 

Company of America LLC submits First 

Revised Sheet 33J.01 et al. to FERC Gas 

Tariff, Seventy Revised Volume 1, to be 

effective 11/1/08. 

Filed Date: 09/12/2008. 

Accession Number: 20080916–0026. 

Comment Date: 5 p.m. Eastern Time 

on Wednesday, September 24, 2008. 

Docket Numbers: RP99–176–166. 

Applicants: Natural Gas Pipeline 

Company of America. 


sroberts on PROD1PC70 with NOTICES