Federal Register / Vol. 79, No. 212 / Monday, November 3, 2014 / Notices 65205 

or documents with the Commission 

relating to the merits of an issue that 

may affect the responsibilities of a 

particular resource agency, they must 

also serve a copy of the document on 

that resource agency. 

k. This application is not ready for 

environmental analysis at this time. 

l. The proposed Sardis Lake Project 

would utilize the following existing 

Corps’ Sardis Lake dam facilities: (1) A 

15,300-foot-long, 97-foot-high earth fill 

embankment dam; (2) a reservoir; and 

(3) outlet works consisting of a concrete 

intake tower, four gated inlets that 

combine to a 560-foot-long and 16.0-foot 

by 18.25-foot ovoid concrete outlet 

tunnel, and a stilling basin. 

The proposed Sardis Lake Project 

would consist of the following new 

facilities: (1) A 510-foot-long, 15.5-footdiameter steel liner installed within the 

existing concrete outlet tunnel; (2) a 50- 

foot-long, 20-foot-high steel-lined, 

reinforced concrete gated bifurcation at 

the end of the existing concrete outlet 

tunnel to divide the flows between the 

existing stilling basin and new 

powerhouse; (3) a 250-foot-long, 15.5- 

foot-diameter steel penstock from the 

bifurcation structure to the forebay; (4) 

a 102.6-foot-long, 78-foot-wide, 50-foothigh forebay; (5) a 120-foot-long, 85- 

foot-wide, 105-foot-high concrete 

powerhouse containing two vertical 

Kaplan generating units with a total 

installed capacity of 14.6 megawatts; (6) 

a 200-foot-long, 100-foot-wide tailrace 

channel; (7) a substation; (8) a 7,097- 

foot-long transmission line consisting of 

a 887-foot-long, 4.160-kilovolt (kV) 

buried cable from the powerhouse to the 

substation, and a 6,210-foot-long 

overhead, 161-kV line from the 

substation to an existing utility-owned 

distribution line; and (9) appurtenant 

facilities. The average annual generation 

would be 52,000 megawatt-hours. 

m. A copy of the application is 

available for electronic review at the 

Commission in the Public Reference 

Room, or may be viewed on the 

Commission’s Web site at http://

www.ferc.gov, using the ‘‘eLibrary’’ link. 

Enter the docket number, excluding the 

last three digits in the docket number 

field, to access the document. For 

assistance, contact FERC Online 

Support. A copy is available for 

inspection and reproduction at the 

address in item h above. 

You may register online at http://

www.ferc.gov/docs-filing/

esubscription.asp to be notified via 

email of new filings and issuances 

related to this or other pending projects. 

For assistance, contact FERC Online 

Support. 

n. Scoping process. 

The Commission staff intends to 

prepare an environmental assessment 

(EA) for the project, in accordance with 

the National Environmental Policy Act. 

The EA will consider both site-specific 

and cumulative environmental impacts 

and reasonable alternatives to the 

proposed action. 

The Commission staff does not 

propose to conduct any on-site scoping 

meetings at this time. Instead, staff is 

soliciting comments, recommendations, 

and information on Scoping Document 

(SD1) issued on October 27, 2014. 

Copies of the SD1 outlining the 

subject areas to be addressed in the EA 

were distributed to the parties on the 

Commission’s mailing list. Copies of the 

SD1 may be viewed on the Web at 

http://www.ferc.gov, using the 

‘‘eLibrary’’ link. Enter the docket 

number, excluding the last three digits 

in the docket number field, to access the 

document. For assistance, call 1–866– 

208–3676, or for TTY, (202) 502–8659. 

Dated: October 27, 2014. 

Kimberly D. Bose, 

Secretary. 

[FR Doc. 2014–25989 Filed 10–31–14; 8:45 am] 

BILLING CODE 6717–01–P 

DEPARTMENT OF ENERGY 

Federal Energy Regulatory 

Commission 

Notice of Commissioner and Staff 

Attendance at North American Electric 

Reliability Corporation Meetings 

The Federal Energy Regulatory 

Commission (Commission) hereby gives 

notice that members of the Commission 

and/or Commission staff may attend the 

following meetings: 

North American Electric Reliability 

Corporation 

Member Representatives Committee and 

Board of Trustees Meetings 

Board of Trustees Corporate Governance 

and Human Resources Committee, 

Finance and Audit Committee, 

Compliance Committee, and 

Standards Oversight and Technology 

Committee Meetings 

The Westin Buckhead Atlanta, 3391 

Peachtree Road NE., Atlanta, GA 

30326 

November 12 (7:30 a.m.–5:00 p.m.) and 

November 13 (8:30 a.m.–12:00 p.m.), 

2014 

Further information regarding these 

meetings may be found at: http://

www.nerc.com/Pages/Calendar.aspx. 

The discussions at the meetings, 

which are open to the public, may 

address matters at issue in the following 

Commission proceedings: 

Docket No. RR14–5, North American 

Electric Reliability Corporation 

Docket No. RR14–6, North American 

Electric Reliability Corporation 

For further information, please 

contact Jonathan First, 202–502–8529, 

or jonathan.first@ferc.gov. 

Dated: October 28, 2014. 

Kimberly D. Bose, 

Secretary. 

[FR Doc. 2014–26066 Filed 10–31–14; 8:45 am] 

BILLING CODE 6717–01–P 

DEPARTMENT OF ENERGY 

Western Area Power Administration 

Pick-Sloan Missouri Basin Program— 

Eastern Division-Rate Order No. 

WAPA–170 

AGENCY: Western Area Power 

Administration, DOE. 

ACTION: Notice of Proposed 

Transmission and Ancillary Services 

Formula Rates. 

SUMMARY: The Western Area Power 

Administration (Western), a power 

marketing administration within the 

Department of Energy (DOE), is 

proposing new formula transmission 

and ancillary services rates for the PickSloan Missouri Basin Program—Eastern 

Division (P–SMBP—ED). The proposed 

formula rates would become effective 

October 1, 2015, and remain in effect 

until September 30, 2020, or until 

Western changes the formula rates 

through another public rate process 

pursuant to 10 CFR part 903, whichever 

is sooner. Western’s Upper Great Plains 

Region (Western-UGP) has joined the 

Southwest Power Pool (SPP) Regional 

Transmission Organization (RTO) 

contingent upon Federal Energy 

Regulatory Commission (FERC) 

approval of Western-UGP’s negotiated 

provisions in the SPP Membership 

Agreement, Bylaws, and Tariff (SPP 

Governing Documents). Transmission 

and ancillary services will be provided 

over Western-UGP facilities under the 

SPP Open Access Transmission Tariff 

(Tariff) by SPP as the transmission 

service provider upon Western-UGP 

transferring functional control to SPP. 

Western-UGP needs to adopt new 

formula rates for these transmission and 

ancillary services so Western-UGP’s 

costs can be recovered under the SPP 

Tariff. These formula rates will provide 

Western sufficient revenue to pay all 

annual costs, including interest 

expenses, and repay required 

investments within the allowable 

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65206 Federal Register / Vol. 79, No. 212 / Monday, November 3, 2014 / Notices 

1 78 FR 65641, November 1, 2013. 

2Rate Order Nos. WAPA–144 and WAPA–148, 

approved on an interim basis, 74 FR 68820, 

December 29, 2009; approved and confirmed by 

FERC on a final basis, 132 FERC ¶61,257, FERC 

Docket No. EF10–3–000, September 23, 2010. 

3Rate Order No. WAPA–168, 79 FR 46798, 

August 11, 2014. 

periods. Western-UGP’s membership in 

SPP and the functional control of its 

facilities will be in accordance with the 

SPP Governing Documents and other 

contractual arrangements with SPP. 

Publication of this Federal Register 

notice begins the formal process for the 

proposed rates. 

DATES: The consultation and comment 

period begins today and will end 

February 2, 2015. Western will present 

a detailed explanation of the proposed 

rates at public information forums that 

will be held on November 19, 2014, 

from 9 a.m. to 12 p.m. CST in Omaha, 

Nebraska, and November 20, 2014, from 

9 a.m. to 12 p.m. CST in Fargo, North 

Dakota. Western will accept written 

comments any time during the 90-day 

consultation and comment period. 

Western will also accept oral and 

written comments at public comment 

forums that will be held on December 

17, 2014, from 9 a.m. to 12 p.m. CST in 

Omaha, Nebraska, and December 18, 

2014, from 9 a.m. to 12 p.m. CST in 

Fargo, North Dakota. 

ADDRESSES: The public information 

forums and public comment forums will 

be held at the Holiday Inn Downtown 

Omaha, located at 1420 Cuming Street, 

Omaha, Nebraska, and at the Ramada 

Plaza & Suites and Conference Center, 

located at 1635 42nd Street South, 

Fargo, North Dakota, on the dates cited 

above. Written comments should be sent 

to: Mr. Robert J. Harris, Regional 

Manager, Upper Great Plains Region, 

Western Area Power Administration, 

2900 4th Avenue North, Billings, MT 

59101–1266; or email: UGPTRates@

wapa.gov. Written comments may also 

be faxed to: (406) 255–2900, attention: 

Linda Cady-Hoffman, Rates Manager. 

Western will post information about the 

rate process on its Web site at: http://

www.wapa.gov/ugp/rates/default.htm. 

Western will also post official 

comments received via letter, fax, and 

email to this Web site. Written 

comments must be received by the end 

of the consultation and comment period 

to ensure they are considered in 

Western’s decision process. 

FOR FURTHER INFORMATION CONTACT: Mr. 

Lloyd Linke, Operations Manager, 

Upper Great Plains Region, Western 

Area Power Administration, 1330 41st 

Street, Watertown, SD 57201; telephone: 

(605) 882–7500; email: Lloyd@wapa.gov; 

or Ms. Linda Cady-Hoffman, Rates 

Manager, Upper Great Plains Region, 

Western Area Power Administration, 

2900 4th Avenue North, Billings, MT 

59101–1266; telephone: (406) 255–2920; 

email: cady@wapa.gov. 

SUPPLEMENTARY INFORMATION: On 

November 1, 2013, Western published a 

Notice of Recommendation to Pursue 

Regional Transmission Organization 

Membership.1 Western-UGP has signed 

a Membership Agreement enabling it to 

join SPP, and the membership 

application is currently before FERC for 

approval. The Western-UGP 

transmission facilities in the P–SMBP— 

ED are currently integrated with 

transmission facilities of Basin Electric 

Power Cooperative and Heartland 

Consumers Power District such that 

transmission services are provided over 

an Integrated System (IS). The IS 

includes approximately 9,848 miles of 

transmission lines, with transmission 

and ancillary services provided under 

Western’s Open Access Transmission 

Tariff, and Western-UGP serving as the 

IS administrator. The IS includes 

transmission facilities located in both 

the Eastern and Western 

Interconnections separated by the Miles 

City DC tie and the Fort Peck Power 

Plant substation. Western-UGP also 

currently operates two Balancing 

Authority Areas within the IS; Western 

Area Power Administration, Upper 

Great Plains West (WAUW), and 

Western Area Power Administration, 

Upper Great Plains East (WAUE), which 

are also separated by the Miles City DC 

tie and the Fort Peck Power Plant 

substation. Western-UGP’s existing rate 

schedules consist of separate rates for 

firm and non-firm transmission service 

and ancillary services rates for the 

transmission facilities in the P–SMBP— 

ED. 

Existing Rate Schedules UGP–NT1, 

UGP–FPT1, UGP–NFPT1, UGP–AS1, 

UGP–AS2, UGP–AS3, UGP–AS4, UGP– 

AS5, UGP–AS6, UGP–AS7, and UGP– 

TSP1 were approved under Rate Order 

Nos. WAPA–144 and WAPA–148 2 for a 

5-year period beginning on January 1, 

2010, and ending December 31, 2014. 

These rates are being extended through 

December 31, 2016, under a separate 

public process.3 Upon achieving final 

FERC approval of membership within 

SPP and transferring functional control 

of Western-UGP’s P–SMBP—ED 

facilities to SPP, Western-UGP will 

merge its WAUE in the Eastern 

Interconnection into SPP’s Balancing 

Authority Area. P–SMBP—ED 

transmission services will no longer be 

available on the IS under Western’s 

Open Access Transmission Tariff, and 

the existing Rate Schedules UGP–NT1, 

UGP–FPT1, UGP–NFPT1, UGP–AS1, 

UGP–AS2, UGP–AS3, UGP–AS4, UGP– 

AS5, UGP–AS6, UGP–AS7, and UGP– 

TSP1 will not be applicable. WesternUGP will, however, retain operation of 

the WAUW in the Western 

Interconnection as the Balancing 

Authority (BA), and will not place the 

portion of its transmission system 

located in the Western Interconnection 

into SPP’s Integrated Marketplace. 

Western-UGP needs to adopt new 

formula rates for use under the SPP 

Tariff. The adoption of new formula 

rates is necessary so that Western may 

recover its revenue requirement of 

eligible transmission facilities under 

SPP’s Tariff. Western-UGP is proposing 

a formula rate to calculate its Annual 

Transmission Revenue Requirement 

(ATRR) for its transmission facilities 

located in both the Eastern and Western 

Interconnections that are to be 

transferred to the functional control of 

SPP and used by SPP to provide 

transmission service in the joint-owner 

Upper Missouri Zone (UMZ or Zone 19) 

under the SPP Tariff. 

Western-UGP is also proposing a 

formula rate schedule WAUGP–AS1 for 

Scheduling, System Control, and 

Dispatch Service (SSCD) for the SPP 

UMZ, which will include the 

transmission facilities in the WAUW. 

Additionally, Western-UGP is proposing 

formula rate schedules to calculate 

charges for applicable ancillary services 

associated with its WAUW in the 

Western Interconnection. These formula 

rate schedules include WAUW–AS3 for 

Regulation and Frequency Response 

Service, WAUW–AS4 for Energy 

Imbalance Service, WAUW–AS5 for 

Operating Reserve—Spinning Reserve 

Service, WAUW–AS6 for Operating 

Reserve—Supplemental Reserve 

Service, and WAUW–AS7 for Generator 

Imbalance Service. The proposed rate 

schedules contain formula-based rates 

that will be recalculated annually. 

Western-UGP intends for the proposed 

formula-based rates to go into effect 

October 1, 2015, and remain in effect 

until September 30, 2020. Annual 

recalculated charges under the formulabased rates are proposed to go into effect 

on January 1, 2016, and annually on 

January 1 thereafter. 

Proposed Formula Transmission Rates 

Consistent with Western-UGP’s 

current formula rates, Western-UGP 

proposes to recover its transmission 

system related expenses and 

investments on a current (forwardlooking) basis by using projections to 

estimate transmission costs for the 

upcoming year, with a ‘‘true up’’ in a 

subsequent year. For transmission 

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Federal Register / Vol. 79, No. 212 / Monday, November 3, 2014 / Notices 65207 

service provided by SPP under SPP’s 

Tariff, Western-UGP will provide its 

ATRR to SPP for calculation of charges 

for transmission service in the jointowner UMZ. SPP will utilize zonal and 

regional load and other applicable 

information, including additional 

annual transmission revenue 

requirements from other transmission 

owners with transmission facilities in 

the joint-owner UMZ, to calculate the 

applicable charges for SPP transmission 

service in the UMZ. The ATRR is 

derived by annualizing Western-UGP’s 

transmission investment and adding 

transmission-related annual costs, 

including operation and maintenance, 

interest, administrative and general 

costs, and depreciation. Western-UGP 

cost data will be submitted to SPP in 

standard revenue requirement 

templates. The annual costs are reduced 

by revenue credits received by WesternUGP under the SPP Tariff. A revenue 

requirement template will be used to 

calculate the ATRR utilizing the cost 

estimates as data inputs. 

Western-UGP will ‘‘true-up’’ the cost 

estimates with Western-UGP’s actual 

costs. Revenue collected in excess of 

Western-UGP’s actual net revenue 

requirement will be returned to 

customers through a credit against rates 

in a subsequent year. Actual revenues 

that are less than the net revenue 

requirement would likewise be 

recovered in a subsequent year. The 

true-up procedure will ensure that 

Western-UGP will recover no more and 

no less than the actual transmission 

costs for the year. 

Data used in the annual recalculation 

of the formula rate effective on January 

1 each year will be made available for 

review and comment on or shortly after 

September 1 each year. Western 

proposes providing customers the 

opportunity to discuss and comment on 

the recalculated rates on or before 

October 31, 2015, and October 31 of 

subsequent years. This procedure will 

ensure that interested parties are aware 

of the data used to calculate the rates. 

This will also provide interested parties 

the opportunity to comment before the 

costs are collected through the formula 

rate. 

Proposed Formula Rate for SSCD 

Service 

Western-UGP proposes a formulabased rate methodology to calculate its 

annual revenue requirement for SSCD 

on a current (forward-looking) basis by 

using projections to estimate 

transmission costs for the upcoming 

year, with a ‘‘true up’’ in a subsequent 

year, to be provided to SPP for inclusion 

in Schedule 1 under the SPP Tariff. 

SSCD is required to schedule the 

movement of power through, out of, 

within, or into the SPP and/or WAUW 

Balancing Authority Area(s). WesternUGP’s annual revenue requirement for 

SSCD, reduced by any portion assessed 

specifically to the loads in the WAUW, 

will be utilized by SPP to calculate the 

regional SPP Schedule 1 rate for SPP 

through and out transactions, and also 

to calculate the zonal SPP Schedule 1 

rate for the UMZ. Western-UGP’s annual 

revenue requirement for SSCD is 

derived by annualizing Western-UGP’s 

applicable transmission-related annual 

costs associated with the provision of 

SSCD service, including operation and 

maintenance, interest, administrative 

and general costs, and depreciation. A 

portion of this revenue requirement may 

be assessed to the loads in the WAUW. 

This rate and rate design only recovers 

Western-UGP’s revenue requirement for 

SSCD service. 

Western-UGP will ‘‘true-up’’ the cost 

estimates with Western-UGP’s actual 

costs. Revenue collected in excess of 

Western-UGP’s actual net revenue 

requirement will be returned to 

customers through a credit against rates 

in a subsequent year. Actual revenues 

that are less than the net revenue 

requirement would likewise be 

recovered in a subsequent year. The 

true-up procedure will ensure that 

Western-UGP will recover no more and 

no less than the actual costs for the year. 

Proposed Formula Rate for Regulation 

and Frequency Response Service 

Western-UGP proposes a formulabased rate methodology for Regulation 

and Frequency Response Service for the 

WAUW as described below. Given the 

SPP Integrated Marketplace will not be 

extended into the Western 

Interconnection, Western-UGP will need 

to provide Regulation and Frequency 

Response Service in the WAUW as the 

BA. Regulation and Frequency Response 

Service in the WAUW is provided 

primarily by United States Army Corps 

of Engineers (Corps) facilities. The 

Corps’ generation fixed charge rate (in 

percent) is applied to the net plant 

investment of the Corps generation 

producing an annual Corps generation 

cost. This cost is divided by the capacity 

at the plants to derive a dollar-permegawatt amount for Corps installed 

capacity ($/MW-year). This dollar-permegawatt amount is then applied to the 

capacity of Corps generation reserved 

for Regulation and Frequency Response 

Service in the WAUW producing the 

annual Corps generation cost to provide 

this service. Western-UGP’s annual 

revenue requirement for Regulation and 

Frequency Response Service is then 

determined by taking the annual Corps 

generation cost to provide this service 

and adding costs associated with the 

purchase of power resources to provide 

Regulation and Frequency Response 

Service to support intermittent 

renewable resources as described below. 

Western-UGP’s annual revenue 

requirement would be recovered under 

the SPP Tariff. 

Western supports the installation of 

renewable sources of energy but 

recognizes that certain operational 

constraints exist in managing the 

significant fluctuations that are a normal 

part of their operation. Western has 

marketed the maximum practical 

amount of power from each of its 

projects, leaving little or no flexibility 

for provision of additional power 

services. Consequently, provided that 

Western-UGP is able to purchase 

additional power resources delivered 

into its WAUW to provide Regulation 

and Frequency Response Service to 

intermittent renewable generation 

resources serving load within WesternUGP’s WAUW, costs for these regulation 

resources will become part of WesternUGP’s Regulation and Frequency 

Response Service charges. However, 

Western-UGP will not regulate for the 

difference between the output of an 

intermittent generator located within 

Western-UGP’s WAUW and a delivery 

schedule from that generator serving 

load located outside of Western-UGP’s 

WAUW. Intermittent generators serving 

load outside Western-UGP’s WAUW 

will be required to pseudo-tie or 

dynamically schedule their generation 

to another Balancing Authority Area. An 

intermittent resource, for the limited 

purpose of these Rate Schedules, is an 

electric generator that is not 

dispatchable and cannot store its fuel 

source, and therefore cannot respond to 

changes in system demand or respond 

to transmission security constraints. 

Proposed Rate for Energy Imbalance 

Service 

Energy Imbalance Service is provided 

when a difference occurs between the 

scheduled and the actual delivery of 

energy to a load located within WesternUGP’s WAUW over a single hour. Given 

the SPP Integrated Marketplace will not 

be extended into the Western 

Interconnection, Western-UGP will need 

to provide Energy Imbalance Service in 

the WAUW as the BA. Western-UGP 

will offer this service, to the extent that 

it is feasible to do so from its own 

resources or from resources available to 

it, when transmission service is 

provided by SPP and used to serve load 

within its WAUW. The transmission 

customer must either purchase this 

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65208 Federal Register / Vol. 79, No. 212 / Monday, November 3, 2014 / Notices 

service or make alternative comparable 

arrangements pursuant to the SPP Tariff 

to satisfy its Energy Imbalance Service 

obligation. A transmission customer 

may be charged a penalty for either 

hourly energy imbalances under this 

Rate Schedule, WAUW–AS4, or hourly 

generator imbalances under Rate 

Schedule WAUW–AS7 for imbalances 

occurring during the same hour, but not 

both, unless the imbalances aggravate 

rather than offset each other. 

Western-UGP proposes that charges 

for service within WAUW be based on 

deviation bands as follows: (i) 

Deviations within +/¥1.5 percent (with 

a minimum of 2 MW) of the scheduled 

transaction to be applied hourly to any 

energy imbalance that occurs as a result 

of transmission customer’s scheduled 

transaction(s) will be netted on a 

monthly basis and settled financially, at 

the end of the month, at 100 percent of 

the average incremental cost for the 

month; (ii) deviations greater than +/

¥1.5 percent up to 7.5 percent (or 

greater than 2 MW up to 10 MW) of the 

scheduled transaction(s) to be applied 

hourly to any energy imbalance that 

occurs as a result of transmission 

customer’s scheduled transaction(s) will 

be settled financially, at the end of each 

month, at 110 percent of incremental 

cost when energy taken by the 

transmission customer in a schedule 

hour is greater than the energy 

scheduled or 90 percent of incremental 

cost when energy taken by a 

transmission customer in a schedule 

hour is less than the scheduled amount; 

and (iii) deviations greater than +/¥7.5 

percent (or 10 MW) of the scheduled 

transaction to be applied hourly to any 

energy imbalance that occurs as a result 

of the transmission customer’s 

scheduled transaction(s) will be settled 

financially, at the end of each month, at 

125 percent of the highest incremental 

cost that occurs that day for energy 

taken by the transmission customer in a 

scheduled hour that is greater than the 

energy scheduled, or 75 percent of the 

lowest incremental cost that occurs that 

day when energy taken by a 

transmission customer is less than the 

scheduled amount. 

Western-UGP’s incremental cost will 

be based upon a representative hourly 

energy index or combination of indexes. 

The index to be used will be posted on 

Western-UGP’s homepage on SPP’s 

Open Access Same-Time Information 

System (OASIS) at least 30 days prior to 

use for determining the Western-UGP 

incremental cost and will not be 

changed more often than once per year 

unless Western-UGP determines that the 

existing index is no longer a reliable 

price index. 

Proposed Formula Rates for Operating 

Reserves Service—Spinning and 

Supplemental 

Given the SPP Integrated Marketplace 

will not be extended into the Western 

Interconnection, Western-UGP will need 

to provide Operating Reserve—Spinning 

Reserve Service and Operating 

Reserve—Supplemental Reserve Service 

in the WAUW as the BA. Western-UGP 

will offer this service under a formulabased rate methodology for Spinning 

Reserve Service and Supplemental 

Reserve Service (Reserve Services); 

except that Western-UGP will substitute 

the reserve requirement of the reserve 

sharing group under which WesternUGP is currently a member for its 

transmission system in the Western 

Interconnection. 

Western-UGP’s annual cost of 

generation for Reserve Services is 

determined by multiplying the Corps’ 

generation fixed charge rate (in percent) 

by the net plant investment of the Corps 

generation producing an annual Corps 

generation cost. This cost is divided by 

the capacity at the plants to derive a 

dollar-per-megawatt amount for Corps 

installed capacity ($/MW-year). This 

dollar-per-megawatt amount is then 

applied to the capacity of Corps 

generation reserved for Reserve Services 

in the WAUW producing the annual 

Corps generation cost to provide this 

service. Western-UGP’s annual revenue 

requirement for Reserve Services is then 

determined by taking the annual Corps 

generation cost to provide this service 

and adding costs associated with the 

current reserve sharing group, if 

applicable. Western-UGP’s annual 

revenue requirement would be 

recovered under the SPP Tariff. This 

rate design recovers only Western-UGP’s 

revenue requirement associated with 

Reserve Services. 

Western-UGP has no long-term 

reserves available beyond its own 

internal requirements. At a customer’s 

request, and if it is capable of doing so, 

Western-UGP will acquire needed 

resources and pass the costs, plus an 

amount for administration, on to the 

requesting customer. The customer is 

responsible to provide the transmission 

to deliver these reserves. In the event 

that Reserve Services are called upon for 

emergency use, Western-UGP will 

assess a charge for energy used at the 

prevailing market energy rate in the 

WAUW. 

Proposed Rate for Generator Imbalance 

Service 

Generator Imbalance Service is 

provided when a difference occurs 

between the output of a generator 

located within Western-UGP’s WAUW 

and a delivery schedule from that 

generator to: (1) Another Balancing 

Authority Area or (2) a load within 

Western-UGP’s WAUW over a single 

hour. Given the SPP Integrated 

Marketplace will not be extended into 

the Western Interconnection, WesternUGP will need to provide Generator 

Imbalance Service in the WAUW as the 

BA. Western-UGP will offer this service, 

to the extent that it is feasible to do so, 

from its own resources or from 

resources available to it, when 

transmission service is used to deliver 

energy from a generator located within 

its WAUW. The transmission customer 

must either purchase this service, or 

make alternative comparable 

arrangements pursuant to the SPP Tariff, 

to satisfy its Generator Imbalance 

Service obligation. A transmission 

customer may be charged a penalty for 

either hourly generator imbalances 

under this Schedule, WAUW–AS7, or 

hourly energy imbalances under Rate 

Schedule WAUW–AS4 for imbalances 

occurring during the same hour, but not 

both, unless the imbalances aggravate 

rather than offset each other. 

Western supports the installation of 

renewable sources of energy but 

recognizes that certain operational 

constraints exist in managing the 

significant fluctuations that are a normal 

part of their operation. Western has 

marketed the maximum practical 

amount of power from each of its 

projects, leaving little or no flexibility 

for provision of additional power 

services. Consequently, Western-UGP 

will not regulate for the difference 

between the output of an intermittent 

generator located within Western-UGP’s 

WAUW and a delivery schedule from 

that generator serving load located 

outside of Western-UGP’s WAUW. 

Intermittent generators serving load 

outside Western-UGP’s WAUW will be 

required to pseudo-tie or dynamically 

schedule their generation to another 

Balancing Authority Area. An 

intermittent resource, for the limited 

purpose of these schedules, is an 

electric generator that is not 

dispatchable and cannot store its fuel 

source, and therefore cannot respond to 

changes in system demand or respond 

to transmission security constraints. 

Western-UGP proposes to base the 

rate on deviation bands as follows: (i) 

Deviations within +/¥1.5 percent (with 

a minimum of 2 MW) of the scheduled 

transaction to be applied hourly to any 

generator imbalance that occurs as a 

result of transmission customer’s 

scheduled transaction(s) will be netted 

on a monthly basis and settled 

financially, at the end of the month, at 

mstockstill on DSK4VPTVN1PROD with NOTICES

Federal Register / Vol. 79, No. 212 / Monday, November 3, 2014 / Notices 65209 

100 percent of the average incremental 

cost; (ii) deviations greater than +/¥1.5 

percent up to 7.5 percent (or greater 

than 2 MW up to 10 MW) of the 

scheduled transaction to be applied 

hourly to any generator imbalance that 

occurs as a result of transmission 

customer’s scheduled transaction(s) will 

be settled financially, at the end of each 

month. When energy delivered in a 

schedule hour from the generation 

resource is less than the energy 

scheduled, the charge is 110 percent of 

incremental cost. When energy 

delivered from the generation resource 

is greater than the scheduled amount, 

the credit is 90 percent of the 

incremental cost; and (iii) deviations 

greater than +/¥7.5 percent (or 10 MW) 

of the scheduled transaction to be 

applied hourly to any generator 

imbalance that occurs as a result of the 

transmission customer’s scheduled 

transaction(s) will be settled at 125 

percent of Western-UGP’s highest 

incremental cost for the day when 

energy delivered in a schedule hour is 

less than the energy scheduled or 75 

percent of Western-UGP’s lowest daily 

incremental cost when energy delivered 

from the generation resource is greater 

than the scheduled amount. As an 

exception, an intermittent resource will 

be exempt from this deviation band and 

will pay the deviation band charges for 

all deviations greater than the larger of 

1.5 percent or 2 MW. 

Deviations from scheduled 

transactions in order to respond to 

directives by the transmission service 

provider, a BA or a reliability 

coordinator shall not be subject to the 

deviation bands identified above and, 

instead, shall be settled financially, at 

the end of the month, at 100 percent of 

incremental cost. Such directives may 

include instructions to correct 

frequency decay, respond to a reserve 

sharing event, or change output to 

relieve congestion. 

Western-UGP’s incremental cost will 

be based on a representative hourly 

energy index or combination of indexes. 

The index to be used will be posted on 

Western-UGP’s homepage on SPP’s 

OASIS at least 30 days prior to use for 

determining the Western-UGP 

incremental cost and will not be 

changed more often than once per year 

unless Western-UGP determines that the 

existing index is no longer a reliable 

price index. 

Legal Authority 

Since the proposed rates constitute a 

major rate adjustment as defined by 10 

CFR part 903, Western will hold both 

public information forums and public 

comment forums. After review of public 

comments, Western will take further 

action on the proposed formula rates 

consistent with 10 CFR part 903. 

Western is establishing transmission 

and ancillary services formula rates for 

the P–SMBP–ED under the DOE 

Organization Act (42 U.S.C 7152); the 

Reclamation Act of 1902 (ch. 1093, 32 

Stat. 388), as amended and 

supplemented by subsequent laws, 

particularly section 9(c) of the 

Reclamation Project Act of 1939 (43 

U.S.C. 485h(c)); section 5 of the Flood 

Control Act of 1944 (16 U.S.C. 825s); 

and other acts that specifically apply to 

the project involved. 

By Delegation Order No. 00–037.00A, 

effective October 25, 2013, the Secretary 

of Energy delegated: (1) The authority to 

develop power and transmission rates to 

Western’s Administrator; (2) the 

authority to confirm, approve, and place 

such rates into effect on an interim basis 

to the Deputy Secretary of Energy; and 

(3) the authority to confirm, approve, 

and place into effect on a final basis, to 

remand, or to disapprove such rates to 

FERC. Existing DOE procedures for 

public participation in power and 

transmission rate adjustments (10 CFR 

part 903) were published on September 

18, 1985 (50 FR 37837). 

Availability of Information 

All brochures, studies, comments, 

letters, memorandums, or other 

documents that Western initiates or uses 

to develop the proposed rates are 

available for inspection and copying at 

the Upper Great Plains Region, Western 

Area Power Administration, 2900 4th 

Avenue North, Billings, Montana. Many 

of these documents are also available on 

Western’s Web site at: http://

www.wapa.gov/ugp/rates/default.htm. 

Ratemaking Procedure Requirements 

Environmental Compliance 

In compliance with the National 

Environmental Policy Act (NEPA) of 

1969, 42 U.S.C. 4321–4347; the Council 

on Environmental Quality Regulations 

for implementing NEPA (40 CFR parts 

1500–1508); and DOE NEPA 

Implementing Procedures and 

Guidelines (10 CFR part 1021), Western 

is in the process of determining whether 

an environmental assessment or an 

environmental impact statement should 

be prepared or if this action can be 

categorically excluded from those 

requirements. 

Determination Under Executive Order 

12866 

Western has an exemption from 

centralized regulatory review under 

Executive Order 12866; accordingly, no 

clearance of this notice by the Office of 

Management and Budget is required. 

Dated: October 24, 2014. 

Mark A. Gabriel, 

Administrator. 

[FR Doc. 2014–26042 Filed 10–31–14; 8:45 am] 

BILLING CODE 6450–01–P 

ENVIRONMENTAL PROTECTION 

AGENCY 

[EPA–HQ–OW–2014–0593; FRL–9918–71– 

OW] 

Proposed Information Collection 

Request; Comment Request; 2015 

Drinking Water Infrastructure Needs 

Survey and Assessment 

(Reinstatement) 

AGENCY: Environmental Protection 

Agency. 

ACTION: Notice. 

SUMMARY: The U.S. Environmental 

Protection Agency (EPA) is planning to 

submit an information collection 

request (ICR), ‘‘2015 Drinking Water 

Infrastructure Needs Survey and 

Assessment (Reinstatement)’’ (EPA ICR 

No. 2234.04, OMB Control No. 2014– 

0274), to the Office of Management and 

Budget (OMB) for review and approval 

in accordance with the Paperwork 

Reduction Act (PRA) (44 U.S.C. 3501 et 

seq.). Before doing so, the EPA is 

soliciting comments on specific aspects 

of the proposed information collection 

as described in this request. This is a 

reinstatement of a previously approved 

information collection activity that was 

discontinued on February 28, 2014. An 

Agency may not conduct or sponsor and 

a person is not required to respond to 

a collection of information unless it 

displays a currently valid OMB control 

number. 

DATES: Comments must be submitted on 

or before January 2, 2015. 

ADDRESSES: Submit your comments, 

referencing Docket ID No. EPA–HQ– 

OW–2014–0593, online using 

www.regulations.gov (our preferred 

method), by email to ow-docket@

epa.gov or by mail to: EPA Docket 

Center, Environmental Protection 

Agency, Mail Code 28221T, 1200 

Pennsylvania Ave. NW., Washington, 

DC 20460. 

The EPA’s policy is that all comments 

received will be included in the public 

docket without change including any 

personal information provided, unless 

the comment includes profanity, threats, 

information claimed to be Confidential 

Business Information (CBI) or other 

information whose disclosure is 

restricted by statute. 

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