58790 Federal Register / Vol. 76, No. 184 / Thursday, September 22, 2011 / Notices 

On October 14, 2011, starting at 8:30 

a.m., the Board will approve the agenda 

and hear remarks from the chair, Jon 

Baron. John Easton, IES Director, will 

introduce Deborah Speece, the newly 

appointed Commissioner of the National 

Center for Special Education Research. 

The Commissioners of the national 

centers will give an overview of recent 

developments at IES. From 9:30 to 10:45 

a.m., Board members will consider the 

topic of ‘‘Peer Review of Research 

Proposals: The IES approach, and 

possible refinements to increase 

findings of policy importance.’’ Opening 

remarks by Anne Ricciuti, the IES 

Deputy Director for Science, will be 

followed by Board discussion. A break 

will take place from 10:45 to 11:00 a.m. 

From 11:00 a.m. to 12:00 noon, the 

Board will take up the topic, ‘‘The 

Administration’s ‘Tiered’ Evidence 

Initiatives in Education and Other 

Areas.’’ Following a brief presentation 

by Kathy Stack, Deputy Associate 

Director for Education and Human 

Resources, Office of Management and 

Budget, Board members will engage in 

a roundtable discussion of the issues 

raised by the presentation. The meeting 

will break for lunch from 12:00 to 1:00 

p.m. 

Following lunch the Board will turn 

to the topic, ‘‘The Congressionallyestablished Committee on Science, 

Technology, Engineering and Math 

Education (CoSTEM)’’ from 1:00 to 2:00 

p.m. After opening remarks by Carl 

Wieman, Associate Director for Science 

at the White House Office of Science 

and Technology Policy, and Co-Chair of 

CoSTEM, the Board will discuss the 

issues raised. 

Next, from 2:00 to 3:20 p.m., the 

Board will address ‘‘Continuous 

Improvement Research: Is it a path for 

achieving program effectiveness in 

large-scale implementation?’’ Following 

opening remarks by Gilbert Botvin of 

Weill Cornell Medical College and 

Anthony Bryk, an NBES member and 

President of the Carnegie Foundation for 

the Advancement of Teaching, the 

Board will engage in roundtable 

discussion. 

An afternoon break from 3:20 to 3:30 

p.m. will precede a discussion of ‘‘NBES 

Annual Reports’’ from 3:30 to 4:10 p.m. 

Monica Herk, NBES’s Executive 

Director, will kickoff the discussion by 

laying out the statutory requirements for 

the annual report and describing how 

they have been produced in the past. 

Her remarks will be followed by Board 

discussion. 

From 4:10 to 4:40 p.m., the Board will 

elect Board leaders. At approximately 

4:40 p.m., there will be closing remarks 

and a consideration of next steps from 

the IES Director and NBES Chair, with 

adjournment scheduled for 5:00 p.m. 

Individuals who will need 

accommodations for a disability in order 

to attend the meeting (e.g., interpreting 

services, assistance listening devices, or 

materials in alternative format) should 

notify Monica Herk no later than 

September 30. We will attempt to meet 

requests for accommodations after this 

date but cannot guarantee their 

availability. The meeting site is 

accessible to individuals with 

disabilities. 

There will not be an opportunity for 

public comment. However, members of 

the public are encouraged to submit 

written comments related to NBES to 

Monica Herk (see contact information 

above). A final agenda will be available 

from Monica Herk (see contact 

information above) on September 30 

and will be posted on the Board Web 

site: http://ies.ed.gov/director/board/ 

agendas/index.asp. 

Records are kept of all Committee 

proceedings and are available for public 

inspection at 555 New Jersey Ave., NW., 

Room 602 K, Washington, DC 20208, 

from the hours of 9 a.m. to 5 p.m., 

Eastern Time Monday through Friday. 

Electronic Access to This Document: 

You may view this document, as well as 

all other documents of this Department 

published in the Federal Register, in 

text or Adobe Portable Document 

Format (PDF) on the Internet at the 

following site: http://www.ed.gov/news/ 

fed-register/index.html. 

To use PDF you must have Adobe 

Acrobat Reader, which is available free 

at this site. If you have questions about 

using PDF, call the U.S. Government 

Printing Office (GPO), toll free at 1–866– 

512–1800; or in the Washington, DC, 

area at (202) 512–0000. 

Note: The official version of this document 

is the document published in the Federal 

Register. Free Internet access to the official 

edition of the Federal Register and the Code 

of Federal Regulations is available on GPO 

Access at: http://www.gpoaccess.gov/nara/ 

index.html. 

John Q. Easton, 

Director, Institute of Education Sciences. 

[FR Doc. 2011–24409 Filed 9–21–11; 8:45 am] 

BILLING CODE 4000–01–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–H, 

CSI–1–H, CEK–1–H, CM–1–H, CC–1–I, 

CK–1–H, CTV–1–H, CTVI–1–A, and 

Replacement-3. The rates were 

approved on an interim basis through 

September 30, 2013. The new rates take 

effect on October 1, 2011, and are 

subject to confirmation and approval on 

a final basis by the Federal Energy 

Regulatory Commission (Commission). 

DATES: Approval of the rate schedules 

on an interim basis is effective October 

1, 2011, through September 30, 2013. 

FOR FURTHER INFORMATION CONTACT: 

Virgil G. Hobbs, III, Assistant 

Administrator, Finance & Marketing, 

Southeastern Power Administration, 

Department of Energy, 1166 Athens 

Tech Road, Elberton, Georgia 30635– 

6711, (706) 213–3800. 

SUPPLEMENTARY INFORMATION: On May 6, 

2009, the Commission confirmed and 

approved on a final basis Wholesale 

Power Rate Schedules CBR–1–G, CSI–1– 

G, CEK–1–G, CM–1–G, CC–1–H, CK–1– 

G, and CTV–1–G for the period from 

October 1, 2008, to September 30, 2013 

(127 FERC ¶ 62,115). Rate Schedule 

CTVI–1 was approved by the 

Administrator, Southeastern Power 

Administration, for a period ending 

September 30, 2013. 

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. 

A current repayment study using 

present rates shows that revenues will 

not be adequate to meet repayment 

criteria. A revised study with a revenue 

requirement increase of $9,570,000, or 

about eighteen percent, shows that these 

rates will be adequate to meet 

repayment criteria. Because the 

estimated annual energy delivered to 

the customers has been reduced, the rate 

increase under the interim operating 

plan is about 40 percent. 

The rate schedules have been 

developed to cover the differing 

marketing arrangements in the 

Cumberland System under normal 

operation conditions. The Rate 

Schedules CBR–1–H, CSI–1–H, and 


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CM–1–H, include rates for customers 

who receive 1500 kilowatt-hours of 

energy annually for each kilowatt of 

capacity. The transmission and 

scheduling arrangements under each of 

these rate schedules are different. Rate 

Schedule CEK–1–H is for East Kentucky 

Power Cooperative, which receives a 

fixed quantity of energy annually from 

projects connected to the TVA 

transmission system plus the output of 

the Laurel Project. Rate Schedule CK–1– 

H is for customers in Kentucky who 

receive 1800 kilowatt-hours of energy 

annually for each kilowatt of capacity. 

Rate Schedule CC–1–I is for customers 

on the Carolina Power & Light Western 

Division, (or Progress Energy Carolinas 

Western Division). 

Rate Schedule CTV–1–H is for TVA 

and TVPPA. Rate Schedule CTVI–1–A is 

for customers inside the TVA system 

who choose a power supplier other than 

TVA. 

Dated: September 12, 2011. 

Daniel B. Poneman, 

Deputy Secretary. 

DEPARTMENT OF ENERGY 

Deputy Secretary 

[Rate Order No. SEPA–55] 

In the Matter of: Southeastern Power 

Administration Cumberland System 

Rates; 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. 

DOE Delegation Order No. 00–037.00, 

issued on December 6, 2001, granted the 

Deputy Secretary authority to confirm, 

approve, and place into effect 

Southeastern’s rates on an interim basis. 

This rate order is issued by the Deputy 

Secretary pursuant to this delegation. 

Background 

On May 9, 2009, the Commission 

issued an order approving Rate 

Schedules CBR–1–G, CSI–1–G, CEK–1– 

G, CM–1–G, CC–1–H, CK–1–G, and 

CTV–1–G on a final basis for the sale of 

power from the Cumberland System 

(127 FERC ¶ 62,115). The Administrator 

of Southeastern Power Administration 

approved Rate Schedule CTVI–1 for a 

period ending September 30, 2013. 

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 

March 7, 2011 (76 FR 12354). The notice 

advised interested parties of a public 

information and comment forum to be 

held in Nashville, Tennessee on May 3, 

2011. By notice published in the 

Federal Register May 20, 2011 (76 FR 

29235), Southeastern extended the 

comment period to July 1, 2011. Written 

comments were received from six 

sources pursuant to this notice. 

The comments have been condensed 

into the following seven major 

categories: 

1. Replacement costs. 

2. Average energy estimate/energy true-up. 

3. Corps Operation and Maintenance (O&M). 

4. Forced payments/repayment study 

method. 

5. Energy shaping. 

6. Dam safety. 

7. SEPA Rates versus Market Cost of Power. 

Southeastern’s response follows each 

comment. 

Category 1: Replacement Costs 

Comment: SEPA should remove 

opportunity projects from projected 

replacements. In future studies, only 

those opportunity projects that are 

approved by the Project Coordinating 

Committee (PCC) for funding through 

the Long-Term Memorandum of 

Agreement (MOA) will be included in 

capitalized investments. It is premature 

to include opportunity projects in the 

current study. 

Comment: SEPA should consider 

revising the cost for the 20-year 

rehabilitation plan so that renewals are 

completed over a 30-year period of time. 

To account for the differences between 

proposed and actual capital 

expenditures, a true-up mechanism for 

capital expenses could be implemented. 

Comment: SEPA rates must be based 

on a realistic estimate of replacement 

costs actually expected to be incurred. 

Response: Southeastern is required to 

include estimates of replacements and 

additions in the repayment study to 

support the proposed rate schedules. As 

a result of the comments received, 

Southeastern has removed the 

opportunity projects from the plan of 

replacements. Southeastern expects 

future replacements and rehabilitation 

of the Cumberland Projects will be 

accomplished through customer 

funding. Because the customers are 

expected to control customer funding, 

they are not expected to fund the 

opportunity projects through the rate 

adjustments established in this 

document. 

The proposed rate schedules are to be 

effective for a two-year period, from 

October 1, 2011 to September 30, 2013. 

Any true-up mechanism incorporated 

into the proposed rate schedules would 

be implemented beyond the term of the 

proposed rate schedules. As such, the 

proposed rate schedules do not include 

a true-up mechanism. 

The rehabilitation plan for the 

Cumberland System is expected to be 

implemented over twenty years. It is 

possible that the implementation of the 

plan may extend to thirty years. 

However, the proposed rate schedules 

have been developed with the present 

twenty-year plan of implementation, as 

Southeastern considers this the best 

estimate currently available. 

Category 2: Average Energy Estimate/ 

Energy True-Up 

Comment: SEPA should consider 

revising the energy sales starting in the 

year 2014 to 3,000,000 hours to account 

for an improved generation due to head 

improvements once Wolf Creek and 

Center Hill project lake levels return to 

normal. 

Comment: Annual energy sales for 

2009 and 2010 were 2,654,328 MWh 

and 2,706,215 MWh respectively. In 

addition, the Tennessee Valley 

Authority (TVA) prepared an 

independent estimate of 2,707,500 MWh 

for energy sales in 2012 and 2013. 

SEPA’s projected energy sales of 

2,538,434 MWh are below actual energy 

sales for 2009 and 2010 and are below 

TVA’s estimate. We recommend SEPA 

utilize TVA’s estimated energy sales of 

2,707,500 MWh for 2012–14. 

Comment: SEPA should not base the 

proposed rate adjustment on an 

arbitrarily determined annual system 

generation amount. 

Response: Based on the comments 

received from the customers in the 

Cumberland System, Southeastern has 

revised the energy estimate used in the 

repayment study. Based on the 

continued Interim operations due to the 

ongoing work at Wolf Creek and Center 

Hill, Southeastern does not use normal 

system generation for the term of the 

Interim Operating Plan and the 

development of rates under the Interim 


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Operating Plan. Southeastern revised 

the proposed rate under the interim 

Operating Plan to include the energy 

estimate determined in TVA’s energy 

model. The primary difference between 

the estimates was that the period of 

record used by TVA is 24 years longer 

than the period of record used by 

Southeastern. This additional data 

allows for multiple year of additional 

river basin hydrology to be considered 

when analyzing system operations and 

in the determination of statistical 

average generation for the system. Both 

the TVA model and Southeastern’s 

records are comprised of actual project 

generation averaged over the respective 

periods of record. The TVA model also 

includes reductions at Wolf Creek and 

Center Hill. 

Category 3: Corps O&M Costs 

Comment: Corps O&M expenses 

included in the repayment study should 

be verified in a detailed accounting. 

Comment: SEPA should conduct a 

more intensive study and analysis of the 

Corps’ request for increased revenues, 

and engage in collaboration with the 

Corps to make further introspective 

study and analysis of the scope and 

need of the Corps’ request. SEPA and 

the Corps through a collaborative effort 

can help ameliorate the extreme impact 

of SEPA’s proposed rate increase by 

both using more aggressive cost controls 

and applying the correct accounting 

procedures to capital expenditures as 

capital assets, thus amortizing those 

over the life of the cost-effective 

improvements to the Corps’ facilities. 

This approach is used in private sector 

accounting principles for capital 

additions. 

Comment: SEPA should reexamine 

Corps operation and maintenance 

(‘‘O&M’’) cost because these costs are 

projected to be higher than a realistic 

forecast would indicate. 

Response: Southeastern recognizes 

that the customers have an interest in 

the maintenance and operation 

expenses and funding of the 

Cumberland Projects. Southeastern 

shares the customers concern over the 

estimated Corps O&M expense included 

in the repayment study to support the 

proposed rate schedules. The estimates 

used to develop the current rate 

schedules in the Cumberland System 

were about 33 percent lower than the 

actual costs incurred. The estimates 

used to develop the proposed rate 

schedules were provided to 

Southeastern and the customers in April 

of 2010. Any variance of the actual costs 

incurred from these estimates will 

impact repayment of the federal 

investment and will be accounted for in 

the next rate adjustment. Southeastern 

will work in collaboration with the 

Corps, the customers, and the O&M 

Committee to ensure that operation and 

maintenance is properly funded and 

charged consistent with generally 

accepted accounting principles. 

Category 4: Forced Payments/ 

Repayment Study Method 

Comment: Following sound business 

principles would dictate that a revenue 

requirement for the last two years of a 

50-year repayment study should not be 

driven by pinch points in years 49 and 

50 of the study. 

Comment: SEPA should consider 

spreading out forced payments for the 

Barkley and Cordell Hull projects over 

multiple years to reduce the required 

payments of these two projects in the 

years 2016 and 2024 respectively. 

Comment: SEPA should revisit its 

ratemaking methodology to reflect a 

more common practice of meeting 

future revenue requirements through a 

series of rate adjustments versus a onetime rate adjustment for the entire study 

period. 

Comment: Utilizing a series of rate 

adjustments will more accurately reflect 

the change in river operations that will 

occur after force majeure conditions are 

lifted in 2014 or 2015. 

Comment: Instead of a single rate 

adjustment to meet a 50-year study 

period, three rate adjustments should be 

made to meet increasing revenue 

requirements in future years. 

Comment: Forced payments for 

Barkley and Cordell Hull should be 

added to the repayment study if they 

will result in lower rates for 2012 and 

2013 (e.g. two years of forced payments 

prior to the Barkley required payment in 

2016, and five years of forced payments 

prior to the Cordell Hull required 

payment in 2024). 

Response: The methodology the 

power marketing administrations are 

required to use is set forth in DOE Order 

RA 6120.2. It describes, among other 

things, the highest interest first method 

of amortization. Section 8c.(3) of the 

Order describes the priority of revenue 

application. 

The power marketing administrations 

adopted highest interest bearing first 

amortization method because it resulted 

in the lowest possible rates. Under this 

method, annual revenues are applied 

first to operating expenses and interest. 

Remaining revenues are then applied 

first to any deferred or unpaid annual 

expense, and then to the Federal 

investment. To the extent possible, 

while still complying with the 

repayment periods established for each 

increment of investment, amortization is 

accomplished by application to the 

highest interest-bearing investment first. 

Southeastern is not required to make 

any payments until the year that an 

investment is due for repayment. 

Southeastern includes early, or 

‘‘forced,’’ payments in a repayment 

study to override the normal priority of 

repayment and to comply with the 

repayment period for the investment. 

Revising the schedule of forced 

payments as the customers have 

requested would result in a slight, 

though not material, increase in the 

revenue requirement than the proposed 

rate schedules were designed to recover. 

This is caused by the increase in 

expensed interest from the later 

payment of high interest rate 

investment. 

Section 7 b. of DOE Order RA6120.2 

defines the ‘‘Cost Evaluation Period’’ for 

the repayment study. The Cost 

Evaluation Period is the period of time 

during which estimates of future costs 

and revenues may be modified to reflect 

changing conditions. For these proposed 

rate schedules, the cost evaluation 

period is two years, fiscal year 2012 and 

fiscal year 2013. Any changes to the 

rates or estimates outside the cost 

evaluation period, as commenters have 

requested, are not permitted under DOE 

Order RA6120.2. 

Category 5: Energy Shaping 

Comment: While this is not expected 

to change over the next two years, the 

affected Customers would encourage 

SEPA to take steps to work with the 

Corps to encourage ‘‘shaping’’ of the 

available resource to provide delivery at 

times when energy markets recognize 

higher demand. This step alone would 

increase the value of the energy-only 

resource that is currently available from 

the Cumberland River basin Corps 

projects. 

Comment: SEPA should press the 

Corps for increased coordination of 

stream flow water management and runof-river energy scheduling to provide 

more on-peak energy and less off-peak 

energy to the extent possible. 

Response: Because of the loss of 

storage operations at the Wolf Creek and 

Center Hill Projects Southeastern is 

unable to provide peaking operations for 

the Cumberland Projects. This is 

expected to continue until the 

rehabilitation work is complete and the 

reservoirs have refilled. Southeastern 

will work with the Corps to provide 

more on-peak energy and less off-peak 

energy to the extent feasible. 

Category 6: Dam Safety 

Comment: The customers want to 

express their concern that the seepage 


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repair costs for Wolf Creek and Center 

Hill as currently classified would 

present another rate hurdle. 

Comment: Proper classification of 

costs for dam safety repairs at Wolf 

Creek and Center Hill is a significant 

concern for SEPA hydropower 

customers. Currently, combined costs 

for these two projects are expected to be 

over $850 million, and, if not properly 

classified under provisions of the Dam 

Safety Act, will result in a significant 

rate increase for hydropower. This 

creates a significant concern that SEPA 

rates may become non-competitive with 

other energy resources available to 

SEPA’s customers. Indeed, the proposed 

rates are already uneconomical at times 

over the next two-year time period. To 

protect the viability of the federal power 

program, SEPA should fully exercise its 

authority under the Flood Control Act of 

1944 to develop the lowest possible 

rates to consumers consistent with 

sound business principles. 

Comment: With the projected 

recovery of the investment needed to 

complete the projects in the Master Plan 

and potential inclusion of the costs 

related to the dam safety repairs at the 

Wolf Creek and Center Hill Projects, the 

affected customers recognize that the 

cost of the SEPA resource may soon 

become uneconomical. 

Comment: The expenditures for 

repairs at the Wolf Creek and Center 

Hill Dam Projects should be classified as 

a dam safety project and therefore 

subject to reimbursement rates in 

accordance with the Dam Safety Act 

(Section 1203 of the WRDA 1986) rather 

than as maintenance costs. 

Response: The rehabilitation work at 

the Wolf Creek and Center Hill Projects 

is currently expected to be complete in 

fiscal year 2014, which is beyond the 

two-year term of these proposed rate 

schedules. The cost associated with this 

rehabilitation work is not included with 

this rate adjustment. 

Southeastern expects to receive from 

the Corps reports on the cost of the 

rehabilitation work that the Corps has 

determined should be allocated to 

power for cost recovery. After 

Southeastern has received these reports, 

Southeastern will develop proposed rate 

schedules to recover the costs. 

Category 7: SEPA Rates Versus Market 

Cost of Power 

Comment: If SEPA is seeking to 

recover from the additional funds 

required to pay for the dam safety 

repairs, the cost of power will likely 

exceed prevailing market rates. If this 

occurs, there’s some speculation that 

some customers will relinquish their 

SEPA allocations. In light of this 

potential scenario, has SEPA performed 

any modeling to calculate how costs 

will be recovered if the customer base 

continues to shrink? 

Comment: In the instance that the 

eventual rate does exceed market rates, 

is there anything that would prevent 

SEPA from considering the option of 

exercising its authority under the Flood 

Control Act to ensure that the rates 

remain the lowest possible consistent 

with sound business principles? 

Response: The provisions of section 5 

of the Flood Control Act of 1944 require 

that Southeastern’s ‘‘Rate Schedules 

shall be drawn having regard to the 

recovery (upon the basis of the 

application of such rate schedules to the 

capacity of the electric facilities of the 

projects) of the cost of producing and 

transmitting such electric energy, 

including the amortization of the capital 

investment allocated to power over a 

reasonable period of years.’’ As such, 

Southeastern is required to develop and 

propose rate schedules that recover the 

cost. If such rates prove to be above 

market, Southeastern will make a 

determination of the appropriate steps 

necessary to market the power and meet 

its repayment obligation. 

Discussion 

System Repayment 

An examination of Southeastern’s 

revised system power repayment study, 

prepared in July, 2011, 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. 

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, 2011, attached 

Wholesale Power Rate Schedules CBR– 

1–H, CSI–1–H, CEK–1–H, CM–1–H, CC– 

1–I, CK–1–H, CTV–1–H, CTVI–1–A, 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, 2011. 

Daniel B. Poneman, 

Deputy Secretary. 

Wholesale Power Rate Schedule 

CBR–1–H 

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 60 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 

Tennessee Valley Authority (TVA). 


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58794 Federal Register / Vol. 76, No. 184 / Thursday, September 22, 2011 / Notices 

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 Power Administration 

(Southeastern) is including three rate 

alternatives. All of the rate alternatives 

have a revenue requirement of 

$59,600,000. 

Rate Scenario 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 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 (Corps) 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 Scenario 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: 

17.69 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 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. 

Percent 

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 Scenario 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 $59,600,000, 

the same as the revenue requirement in 

Scenarios 1 and 3. The Rate Scenario 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 Scenario 

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 Scenario 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: 

$4.245 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 Southeastern 

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: 


jlentini on DSK4TPTVN1PROD with NOTICESEN22SE11.000</GPH>
Federal Register / Vol. 76, No. 184 / Thursday, September 22, 2011 / Notices 58795 

Wholesale Power Rate Schedule 

CSI–1–H 

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 60 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 

Tennessee Valley Authority (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 Power Administration 

(Southeastern) is including three rate 

alternatives. All of the rate alternatives 

have a revenue requirement of 

$59,600,000. 

Rate Scenario 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 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 (Corps) 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 Scenario 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: 

17.69 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 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 Scenario 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 $59,600,000, 

the same as the revenue requirement in 

Scenarios 1 and 3. The Rate Scenario 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 Scenario 

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 Scenario 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: 

$4.245 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 Southeastern 

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: 


jlentini on DSK4TPTVN1PROD with NOTICES
58796 Federal Register / Vol. 76, No. 184 / Thursday, September 22, 2011 / Notices 

Wholesale Power Rate Schedule 

CEK–1–H 

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 60 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 the Tennessee 

Valley Authority (TVA) on its side of 

the delivery point. 

Southeastern Power Administration 

(Southeastern) is including three rate 

alternatives. All of the rate alternatives 

have a revenue requirement of 

$59,600,000. 

Rate Scenario 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 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 (Corps) 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 Scenario 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: 

17.69 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 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 Scenario 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 $59,600,000, 

the same as the revenue requirement in 

Scenarios 1 and 3. The Rate Scenario 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 Scenario 

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 Scenario 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: 

$2.950 per kilowatt/month of total 

contract demand. 

Energy Charge: 

10.358 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 


jlentini on DSK4TPTVN1PROD with NOTICESEN22SE11.001</GPH>
Federal Register / Vol. 76, No. 184 / Thursday, September 22, 2011 / Notices 58797 

contract demand; provided, that the 

combined schedule of all Southeastern 

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: 

Wholesale Power Rate Schedule 

CM–1–H 

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 60 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 (TVA) 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 Power Administration 

(Southeastern) is including three rate 

alternatives. All of the rate alternatives 

have a revenue requirement of 

$59,600,000. 

Rate Scenario 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 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 (Corps) 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 Scenario 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: 

17.69 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 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. 

Percent 

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 Scenario 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 $59,600,000, 

the same as the revenue requirement in 

Scenarios 1 and 3. The Rate Scenario 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 Scenario 

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 Scenario 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: 

$4.245 per kilowatt/month of total 

contract demand. 

Energy Charge: 

None. 


jlentini on DSK4TPTVN1PROD with NOTICESEN22SE11.002</GPH>
58798 Federal Register / Vol. 76, No. 184 / Thursday, September 22, 2011 / Notices 

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 Southeastern 

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: 

Wholesale Power Rate Schedule 

CC–1–I 

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 60 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 (TVA) 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 Power Administration 

(Southeastern) is including three rate 

alternatives. All of the rate alternatives 

have a revenue requirement of 

$59,600,000. 

Rate Scenario 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 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 (Corps) 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 Scenario 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: 

17.69 mills per kilowatt-hour. 

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 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. 

Percent 

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. 

Percent 

French Broad EMC ....................... 66.667 

Haywood EMC .............................. 19.512 

Town of Waynesville .................... 13.821 

Energy to be Furnished by the 

Government: 


jlentini on DSK4TPTVN1PROD with NOTICESEN22SE11.003</GPH>
Federal Register / Vol. 76, No. 184 / Thursday, September 22, 2011 / Notices 58799 

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 Scenario 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 $59,600,000, 

the same as the revenue requirement in 

Scenarios 1 and 3. The Rate Scenario 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 Scenario 

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 Scenario 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: 

$4.832 per kilowatt/month of total 

contract demand. 

Energy Charge: 

None. 

CP&L Transmission Charge: 

$1.3334 per kilowatt/month of total 

contract demand (As of July 2011 and 

provided for illustrative purposes.). 

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–H 

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 60 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 (TVA) 

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 Power Administration 

(Southeastern) is including three rate 

alternatives. All of the rate alternatives 

have a revenue requirement of 

$59,600,000. 

Rate Scenario 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 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 (Corps) 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 Scenario 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: 

17.69 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 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. 

Percent 

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 Scenario 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 


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under this alternative is $59,600,000, 

the same as the revenue requirement in 

Scenarios 1 and 3. The Rate Scenario 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 Scenario 

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 Scenario 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: 

$4.245 per kilowatt/month of total 

contract demand. 

Energy Charge: 

None. 

Additional Energy Charge: 

10.358 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 Southeastern 

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–H 

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 Power Administration 

(Southeastern) is including three rate 

alternatives. All of the rate alternatives 

have a revenue requirement of 

$59,600,000. 

Rate Scenario 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 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 (Corps) 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 Scenario 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: 

17.69 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 Scenario 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 $59,600,000, 

the same as the revenue requirement in 

Scenarios 1 and 3. The Rate Scenario 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 Scenario 

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. 


jlentini on DSK4TPTVN1PROD with NOTICES
Federal Register / Vol. 76, No. 184 / Thursday, September 22, 2011 / Notices 58801 

Rate Scenario 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: 

$2.779 per kilowatt/month of total 

contract demand. 

Energy Charge: 

None. 

Additional Energy Charge: 

10.358 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 

percent [2%], 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: 

Wholesale Power Rate Schedule 

CTVI–1–A 

Availability: 

This rate schedule shall be available 

to customers (hereinafter called the 

Customer) who are or were formerly in 

the Tennessee Valley Authority 

(hereinafter called TVA) service area. 

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 the Customer. 

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. 

Southeastern Power Administration 

(Southeastern) is including three rate 

alternatives. All of the rate alternatives 

have a revenue requirement of 

$59,600,000. 

Rate Scenario 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 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 (Corps) 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 Scenario 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: 

17.69 mills per kilowatt-hour. 

Transmission Charge: 

The initial charge for transmission 

and Ancillary Services will be the 


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58802 Federal Register / Vol. 76, No. 184 / Thursday, September 22, 2011 / Notices 

Customer’s ratable share of the charges 

for transmission, distribution, and 

ancillary services paid by the 

Government. The charges for 

transmission and ancillary services are 

governed by and subject to refund based 

upon the determination in proceedings 

before the Federal Energy Regulatory 

Commission (FERC) or other overseeing 

entity involving the TVA’s and other 

transmission provider’s Open Access 

Transmission Tariff (OATT). 

Proceedings before FERC or other 

overseeing entity involving the OATT or 

the Distribution charge may result in the 

separation of charges currently included 

in the transmission rate. In this event, 

the Government may charge the 

Customer for any and all separate 

transmission, ancillary services, and 

distribution charges paid by the 

Government in behalf of the Customer. 

These charges could be recovered 

through a capacity charge or an energy 

charge, as determined by the 

Government. 

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 Scenario 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 $59,600,000, 

the same as the revenue requirement in 

Scenarios 1 and 3. The Rate Scenario 2 

will receive revenues from capacity that 

can be scheduled and the remainder 

from energy, at charges that will be 

determined at the time. 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. The Customer will pay the 

same rate for capacity and energy as 

TVA. The Customer will pay their 

ratable share of any transmission 

charges paid in behalf of the Customer. 

Rate Scenario 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: 

$2.779 per kilowatt/month of total 

contract demand. 

Energy Charge: 

None. 

Additional Energy Charge: 

10.358 mills per kilowatt-hour. 

Transmission Charge: 

The initial charge for transmission 

and Ancillary Services will be the 

Customer’s ratable share of the charges 

for transmission, distribution, and 

ancillary services paid by the 

Government. The charges for 

transmission and ancillary services are 

governed by and subject to refund based 

upon the determination in proceedings 

before FERC or other overseeing entity 

involving the TVA’s and other 

transmission provider’s Open Access 

Transmission Tariff (OATT). 

Proceedings before FERC or other 

overseeing entity involving the OATT or 

the Distribution charge may result in the 

separation of charges currently included 

in the transmission rate. In this event, 

the Government may charge the 

Customer for any and all separate 

transmission, ancillary services, and 

distribution charges paid by the 

Government in behalf of the Customer. 

These charges could be recovered 

through a capacity charge or an energy 

charge, as determined by the 

Government. 

Energy To Be Made Available: 

The energy will be scheduled by TVA 

and the Customer will receive their 

ratable share, in accordance with the 

Government-Customer Contract. Energy 

shall be accounted for, in accordance 

with agreements with TVA. 

The Customer will receive a ratable 

share of their capacity, in accordance 

with the Government-Customer 

Contract. 

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. 

The customer will receive a ratable 

share of this capacity. 

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 the Customer 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: 

Wholesale Rate Schedule Replacement3 

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. 

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 


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Federal Register / Vol. 76, No. 184 / Thursday, September 22, 2011 / Notices 58803 

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. 2011–24224 Filed 9–21–11; 8:45 am] 

BILLING CODE 6450–01–P 

DEPARTMENT OF ENERGY 

Federal Energy Regulatory 

Commission 

[Docket No. RD11–4–000] 

Commission Information Collection 

Activities (FERC–725A); Comment 

Request; Submitted for OMB Review 

AGENCY: Federal Energy Regulatory 

Commission. 

ACTION: Notice. 

SUMMARY: In compliance with the 

requirements of section 3507 of the 

Paperwork Reduction Act of 1995, 44 

U.S.C. 3507, the Federal Energy 

Regulatory Commission (Commission or 

FERC) has submitted the information 

collection described below to the Office 

of Management and Budget (OMB) for 

review of the information collection 

requirements. Any interested person 

may file comments directly with OMB 

and should address a copy of those 

comments to the Commission as 

explained below. The Commission 

issued a Notice in the Federal Register 

(76 FR 23801, 04/28/2011) requesting 

public comments. FERC received no 

comments on the FERC–725A and has 

made this notation in its submission to 

OMB. 

DATES: Comments in consideration of 

the collection of information are due 

October 24, 2011. 

ADDRESSES: Comments may be filed 

either electronically (eFiled) or in paper 

format, and should refer to Docket No. 

RD11–4–000. Documents must be 

prepared in an acceptable filing format 

and in compliance with Commission 

submission guidelines at: http://www.

ferc.gov/help/submission-guide.asp. 

eFiling instructions are available at: 

http://www.ferc.gov/docs-filing/efiling.

asp. First time users must follow 

eRegister instructions at: http://www.

ferc.gov/docs-filing/eregistration.asp, to 

establish a username and password 

before eFiling. The Commission will 

send an automatic acknowledgement to 

the sender’s e-mail address upon receipt 

of eFiled comments. Commenters 

making an eFiling should not make a 

paper filing. Commenters that are not 

able to file electronically must send an 

original of their comments to: Federal 

Energy Regulatory Commission, 

Secretary of the Commission, 888 First 

Street, NE., Washington, DC 20426. 

Users interested in receiving 

automatic notification of activity in this 

docket may do so through eSubscription 

at http://www.ferc.gov/docs-filing/

esubscription.asp. In addition, all 

comments and FERC issuances may be 

viewed, printed or downloaded 

remotely through FERC’s eLibrary at 

http://www.ferc.gov/docs-filing/elibrary.

asp, by searching on Docket No. RD11– 

4–000. For user assistance, contact 

FERC Online Support by e-mail at 

ferconlinesupport@ferc.gov, or by phone 

at: (866) 208–3676 (toll-free), or (202) 

502–8659 for TTY. 

FOR FURTHER INFORMATION CONTACT: 

Ellen Brown may be reached by e-mail 

at DataClearance@FERC.gov, telephone 

at (202) 502–8663, and fax at (202) 273– 

0873. 

SUPPLEMENTARY INFORMATION: The 

information collected under the order in 

Docket No. RD11–4–000 under the 

requirements of FERC–725A, 

‘‘Mandatory Reliability Standards for 

the Bulk-Power System’’ (OMB No. 

1902–0244), is required by Commissionapproved Reliability Standard EOP– 

008–1 (Loss of Control Center 

Functionality) that requires reliability 

coordinators, transmission operators, 

and balancing authorities to have an 

operating plan and facilities for backup 

functionality to ensure Bulk-Power 

System reliability in the event that a 

control center becomes inoperable. The 

standard consists of eight requirements. 

Requirement R1 requires each 

applicable entity to have a current 

operating plan describing the manner in 

which it will continue to meet its 

functional obligations in the event that 

its primary control center functionality 

is lost. Requirement R2 instructs each 

applicable entity to have a copy of its 

current plan for backup functionality at 

its primary control center and at the 

location providing backup functionality. 

Requirement R3 mandates that each 

reliability coordinator have a backup 

control center that provides 

functionality sufficient to maintain 

compliance with all Reliability 

Standards that depend on primary 

control center functionality. 

Requirement R4 directs balancing 

authorities and transmission operators 

to have a backup functionality, either 

through a facility or contracted services, 

to maintain compliance with all 

Reliability Standards that depend on 

their primary control center 

functionality. Requirement R5 requires 

each applicable entity to review 

annually and approve its plan for 

backup functionality. Requirement R6 

mandates that primary and backup 

functionality cannot depend on each 

other, and Requirement R7 requires 

each applicable entity to annually test 

and document the results of its plan 

demonstrating the transition time 

between the simulated loss of the 

primary control center and the full 

implementation of the backup 

functionality. Finally, each reliability 

coordinator, balancing authority or 

transmission operator that experiences a 

loss of either primary or backup 

functionality anticipated to last for more 

than six months must, in accordance 

with Requirement R8, provide a plan to 

its Regional Entity within six calendar 

months of the date when functionality 

is lost showing how it will re-establish 

such functionality. 

Rather than creating entirely new 

obligations with respect to the loss of 

control center functionality, Reliability 

Standard EOP–008–1 upgrades existing 

planning requirements. The standard 

does not impose entirely new burdens 

on the effected entities, but it does 

impose new requirements regarding the 

approval, placement, documentation 

and updating of plans as well as 

requires entities that may not already 

possess backup functionality to obtain, 

possibly through contractual 

arrangements, backup capabilities. 

Burden Statement: Public reporting 

burden resulting from the approval of 

Reliability Standard EOP–008–1 is 

estimated as: 

Changes to FERC–725A data collection 

Number of 

respondents 

annually 

(A) 

Number of 

responses per 

respondent 

(B) 

Average 

burden hours 

per response 

(C) 

Total annual 

hours 

( A × B × C ) 

Review and possible revision of plan (one-time) ................................... 215 1 20 ............................ 4,300 


jlentini on DSK4TPTVN1PROD with NOTICES