2025 Resource Pool-Sierra Nevada Customer Service Region, 28039-28041 [2019-12751]
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28039
Federal Register / Vol. 84, No. 116 / Monday, June 17, 2019 / Notices
for such decision shall be that, given the
configuration of the Customer’s and
Southwestern’s systems, Southwestern
will determine, in its sole judgment and
at its sole option, whether the power
factor calculation more accurately
assesses the detrimental impact on
Southwestern’s system when the above
formula is calculated for a single
physical point of delivery, a
combination of physical points of
delivery, or for an interconnection as
specified by an Interconnection
Agreement.
Southwestern, at its sole option, may
reduce or waive Power Factor Penalties
when, in Southwestern’s sole judgment,
low power factor conditions were not
detrimental to the System of
Southwestern due to particular loading
and voltage conditions at the time the
power factor dropped below 95 percent
lagging.
4.
Hydro Peaking Power Miscellaneous
Rates, Terms, and Conditions
4.1. Real Power Losses
Customers are required to self-provide
all Real Power Losses for non-Federal
energy transmitted by Southwestern on
behalf of such Customers under the
provisions detailed below.
Real Power Losses are computed as
four (4) percent of the total amount of
non-Federal energy transmitted by
Southwestern. The Customer’s monthly
Real Power Losses are computed each
month on a megawatthour basis as
follows:
ML = 0.04 × NFE
with the factors defined as follows:
ML = The total monthly loss energy,
rounded to the nearest
megawatthour, to be scheduled by a
Customer for receipt by
Southwestern for Real Power Losses
associated with non-Federal energy
transmitted on behalf of such
Customer; and
NFE = The amount of non-Federal
energy that was transmitted by
Southwestern on behalf of a
Customer during a particular
month.
The Customer must schedule or cause
to be scheduled to Southwestern, Real
Power Losses for which it is responsible
subject to the following conditions:
4.1.1. The Customer shall schedule
and deliver Real Power Losses back to
Southwestern during the second month
after they were incurred by
Southwestern in the transmission of the
Customer’s non-Federal power and
energy over the System of Southwestern
unless such Customer has accounted for
Real Power Losses as part of a metering
arrangement with Southwestern.
4.1.2. On or before the twentieth day
of each month, Southwestern shall
determine the amount of non-Federal
loss energy it provided on behalf of the
Customer during the previous month
and provide a written schedule to the
Customer setting forth hour-by-hour the
quantities of non-Federal energy to be
delivered to Southwestern as losses
during the next month.
4.1.3. Real Power Losses not delivered
to Southwestern by the Customer,
according to the schedule provided,
during the month in which such losses
are due shall be billed by Southwestern
to the Customer to adjust the end-ofmonth loss energy balance to zero (0)
megawatthours and the Customer shall
be obliged to purchase such energy at
the following rates:
Rate per
kilowatthour
Months associated with charge
khammond on DSKBBV9HB2PROD with NOTICES
March, April, May, October, November, December ............................................................................................................................
January, February, June, July, August, September ............................................................................................................................
4.1.4. Real Power Losses delivered to
Southwestern by the Customer in excess
of the losses due during the month shall
be purchased by Southwestern from the
Customer at a rate per megawatthour
equal to Southwestern’s rate per
megawatthour for Supplemental
Peaking Energy, as set forth in
Southwestern’s then-effective Rate
Schedule for Hydro Peaking Power to
adjust such hourly end-of-month loss
energy balance to zero (0)
megawatthours.
4.2.1 Applicability of Peaking Energy
Schedule Submission Time
4.2. Peaking Energy Schedule
Submission Time
Not more than once annually, the
Peaking Energy Schedule Submission
Time of 2:30 p.m. CPT, as noted in
Section 4.2 of this Rate Schedule, may
be adjusted by the Administrator,
Southwestern, to a time no earlier than
2:00 p.m. CPT and no later than 3:00
p.m. CPT.
Southwestern’s Peaking Energy
Schedule Submission Time is on or
before 2:30 p.m. Central Prevailing Time
(CPT), as adjusted by the Administrator,
Southwestern, in accordance with
Section 4.2.2 in this Rate Schedule, of
the day preceding the day for the
delivery of Peaking Energy. The Peaking
Energy Schedule Submission Time
supersedes the Peaking Energy schedule
submission time provided in the
Customer’s Power Sales Contract,
pursuant to Section 4.2.1 of this Rate
Schedule.
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16:34 Jun 14, 2019
Jkt 247001
The Peaking Energy Schedule
Submission Time shall apply to the
scheduling of Peaking Energy. The
Peaking Energy Schedule Submission
Time shall not apply to the scheduling
of Supplemental Peaking Energy or to
Contract Support Arrangements.
4.2.2 Procedure for Adjusting the
Peaking Energy Schedule Submission
Time
4.2.2.1 Determination of Need to Adjust
the Peaking Energy Schedule
Submission Time
The Administrator, Southwestern,
will make a determination on the need
to adjust the Peaking Energy Schedule
Submission Time based on
Southwestern’s studies involving
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$0.15
0.30
financial analysis, regional energy
market conditions, and/or operational
considerations.
4.2.2.2 Notification of Peaking Energy
Schedule Submission Time Adjustment
The Administrator, Southwestern,
will notify customers of the
determination to adjust the Peaking
Energy Schedule Submission Time in
writing no later than 30 calendar days
prior to the effective date of the Peaking
Energy Schedule Submission Time
adjustment.
[FR Doc. 2019–12753 Filed 6–14–19; 8:45 am]
BILLING CODE 6450–01–P
DEPARTMENT OF ENERGY
Western Area Power Administration
2025 Resource Pool—Sierra Nevada
Customer Service Region
Western Area Power
Administration, DOE.
AGENCY:
Final power allocations from
Central Valley and Washoe Projects.
ACTION:
E:\FR\FM\17JNN1.SGM
17JNN1
28040
Federal Register / Vol. 84, No. 116 / Monday, June 17, 2019 / Notices
Western Area Power
Administration (WAPA) announces the
final 2025 Resource Pool allocations
from the Central Valley and Washoe
Projects under its 2025 Power Marketing
Plan (Marketing Plan) for the Sierra
Nevada Customer Service Region (SNR).
This notice includes a summary of the
comments received on WAPA’s
proposed 2025 Resource Pool
allocations and WAPA’s responses.
DATES: The final 2025 Resource Pool
allocations begin July 17, 2019.
FOR FURTHER INFORMATION CONTACT: Ms.
Sandee Peebles, Public Utilities
Specialist, Western Area Power
Administration, Sierra Nevada
Customer Service Region, 114 Parkshore
Drive, Folsom, CA 95630–4710, (916)
353–4454, peebles@wapa.gov.
SUPPLEMENTARY INFORMATION:
SUMMARY:
Background
WAPA published the Marketing Plan
on August 15, 2017 (82 FR 38675) to
define how SNR will market
hydropower from the Central Valley and
Washoe projects beginning January 1,
2025, and ending December 31, 2054.
SNR’s current marketing plan and
contracts expire on December 31, 2024.
As part of the Marketing Plan, SNR will
withdraw 2 percent of the existing
marketable resource from existing
customers, also known as Base
Resource, to create a resource pool.
WAPA is marketing the 2-percent
resource pool to eligible preference
entities.
WAPA published the Call for 2025
Resource Pool Applications in the
Federal Register on March 8, 2018 (83
FR 9851), and applications were due by
May 7, 2018. On July 13, 2018, WAPA
extended the deadline to file
applications to August 13, 2018 (83 FR
32664). In response to the Call for 2025
Resource Pool Applications, WAPA
received 37 applications. After
reviewing and considering the
applications, WAPA published the
Proposed 2025 Resource Pool
Allocations in the Federal Register on
February 12, 2019 (84 FR 3441) and
opened a 30-day comment period. The
comment period ended on March 14,
2019. Summaries of the comments
received and WAPA’s responses are
provided below. After considering all
comments, WAPA has finalized the
proposed power allocations as
discussed herein.
Responses to Comments Received on
the Proposed 2025 Resource Pool
Allocations
During the comment period, WAPA
received three letters commenting on
the proposed allocations from the 2025
Resource Pool. WAPA reviewed and
considered all comments made.
Summaries of the comments and
responses are provided below.
Comment: All commenters expressed
appreciation and support for the
proposed 2025 Resource Pool
allocations.
Response: WAPA notes the comments
of support for its 2025 Resource Pool
allocations.
Comment: All commenters requested
additional allocations if additional Base
Resource becomes available.
Response: WAPA will allocate any
additional available power, as discussed
below, in the Additional Base Resource
section.
Final 2025 Resource Pool Allocations
The final 2025 Resource Pool allottees
are listed below. The allocations are
expressed as percentages of the Base
Resource with an estimated megawatthour (MWh) amount of each allocation.
The estimated MWh for each allocation
assumes an estimated average annual
Base Resource of 3,342,000 MWh and
are rounded to the nearest MWh. The
actual amount of Base Resource a
customer will receive will vary hourly,
daily, monthly, and annually depending
on hydrology and other constraints
governing Central Valley Project
operations. The final allocations are as
follows:
Base
Resource
allocation
(%)
khammond on DSKBBV9HB2PROD with NOTICES
Allottee
Army Air Force Exchange .......................................................................................................................................
California State University, Sacramento ..................................................................................................................
Cawelo Water District ..............................................................................................................................................
Eastside Power Authority ........................................................................................................................................
Fallon, City of ...........................................................................................................................................................
Hoopa Valley Tribe ..................................................................................................................................................
Kirkwood Meadows Public Utilities District ..............................................................................................................
Lower Tule Irrigation District ....................................................................................................................................
Merced Irrigation District ..........................................................................................................................................
Modesto Irrigation District ........................................................................................................................................
Monterey Bay Community Power ............................................................................................................................
Orange Cove Irrigation District ................................................................................................................................
Placer County Water Agency ..................................................................................................................................
Reclamation District 108 ..........................................................................................................................................
Regents of the University of California ....................................................................................................................
Roseville, City of ......................................................................................................................................................
Sacramento Municipal Utility District .......................................................................................................................
Santa Clara Water District .......................................................................................................................................
Silicon Valley Clean Energy Authority .....................................................................................................................
Sonoma County Water Agency ...............................................................................................................................
Stockton, Port of ......................................................................................................................................................
Truckee Donner Public Utility District ......................................................................................................................
Turlock Irrigation District ..........................................................................................................................................
University of California, Davis .................................................................................................................................
Water Resources, California Department of ...........................................................................................................
Woodland Davis Clean Water Agency ....................................................................................................................
Zone 7, Alameda County Flood Control & Water Conservation District .................................................................
VerDate Sep<11>2014
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Jkt 247001
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E:\FR\FM\17JNN1.SGM
17JNN1
Estimated
MWh
0.03960
0.01106
0.00373
0.00362
0.01988
0.00158
0.03793
0.00197
0.10079
0.30470
0.35347
0.02382
0.00394
0.00072
0.14688
0.00979
0.01735
0.00365
0.32467
0.00360
0.01155
0.03716
0.32956
0.01949
0.14398
0.04371
0.00180
1,323
370
125
121
664
53
1,268
66
3,368
10,183
11,813
796
132
24
4,909
327
580
122
10,850
120
386
1,242
11,014
651
4,812
1,461
60
2.00000
66,840
Federal Register / Vol. 84, No. 116 / Monday, June 17, 2019 / Notices
Additional Base Resource
Under the Marketing Plan, there may
be future opportunities for entities to
receive a Base Resource allocation from
WAPA, for instance:
1. If an allocation is withdrawn
because an allottee or an existing
customer is unable to execute a contract
or secure transmission arrangements for
the delivery of power by the prescribed
dates.
2. A customer surrenders an
allocation.
3. An allottee’s or existing customer’s
base resource allocation is greater than
its need.
If additional base resource is available
for reallocation prior to the creation of
the next resource pool in 2040, WAPA,
at its discretion and sole determination,
reserves the right to reallocate the
additional base resource through
bilateral negotiations. WAPA also
reserves the right to offer any additional
base resource to (1) eligible entities who
submitted applications during the 2025
Call for Applications, (2) existing
customers, (3) new preference entities,
or (4) any entity on a short-term basis.
khammond on DSKBBV9HB2PROD with NOTICES
Contracting Process
SNR will offer existing customers 98
percent of their current base resource
allocations. For existing customers who
received a resource pool allocation, the
additional allocation will be included
with their remaining base resource
allocations.
After the effective date of this notice,
SNR will begin the contracting process.
WAPA will send all existing customers
and new allottees a pro forma electric
service contract to purchase the base
resource. All existing customers and
new allottees must execute and return
SNR’s pro forma electric service
contract within 6 months of the date of
WAPA’s letter submitting the pro forma
contract, unless otherwise agreed to in
writing by SNR. SNR reserves the right
to withdraw and reallocate any power
allocation if an existing customer or
allottee does not execute the electric
service contract within the 6-month
period. The date of initial service under
these contracts is January 1, 2025, and
these contracts will remain in effect
until midnight of December 31, 2054.
SNR solely determines the terms,
conditions, rates, or charges of its power
contracts. SNR will work with existing
customers and new allottees to develop
customized products, if requested, to
meet their needs. Each existing
customer and new allottee is
responsible for obtaining transmission
arrangements for delivery of power to its
load. Upon request, SNR may assist in
VerDate Sep<11>2014
16:34 Jun 14, 2019
Jkt 247001
obtaining transmission arrangements for
delivery of power; however, it is the
customer’s or allottee’s ultimate
responsibility to secure necessary
transmission arrangements.
Authorities
The Marketing Plan, published in the
Federal Register (82 FR 38675) on
August 15, 2017, was established under
the Department of Energy Organization
Act (42 U.S.C. 7101 et seq.); the
Reclamation Act of June 17, 1902 (Pub.
L. 57–161, 32 Stat. 388), as amended
and supplemented by subsequent
enactments, particularly section 9(c) of
the Reclamation Project Act of 1939 (43
U.S.C. 485h(c)); and other acts
specifically applicable to the projects
involved. Allocating power from the
resource pool falls within the Marketing
Plan and is covered by this authority.
Regulatory Procedure Requirements
Environmental Compliance
In accordance with DOE National
Environmental Policy Act Implementing
Procedures (10 CFR 1021), WAPA has
determined this action falls within a
class of action B4.1 contracts, policies,
marketing, and allocation plans for
electric power, in Appendix B to
Subpart D to Part 1021—Categorical
Exclusion Applicable to Specific
Agency Actions.
Determination Under Executive Order
12866
WAPA 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 requred.
Dated: June 4, 2019.
Mark A. Gabriel,
Administrator.
[FR Doc. 2019–12751 Filed 6–14–19; 8:45 am]
BILLING CODE 6450–01–P
ENVIRONMENTAL PROTECTION
AGENCY
[EPA–HQ–OPP–2019–0050; FRL–9994–71]
Pesticide Emergency Exemptions;
Agency Decisions and State and
Federal Agency Crisis Declarations
Environmental Protection
Agency (EPA).
ACTION: Notice.
AGENCY:
EPA has granted emergency
exemptions under the Federal
Insecticide, Fungicide, and Rodenticide
Act (FIFRA) for use of pesticides as
listed in this notice. The exemptions
were granted during the period October
SUMMARY:
PO 00000
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28041
1, 2018 to March 30, 2019, except for
one granted in September 2018, to
control unforeseen pest outbreaks. The
item for the exemption granted in
September 2018 was issued to the
Wyoming Department of Agriculture for
the use of indaziflam on rangeland,
pastures, and areas subject to the
conservation reserve program to control
Medusahead and Ventenata. From the
previous notice for this exemption,
published in the notice for pesticide
emergency exemption decisions from
the February 14, 2019 Federal Register
(84 FR 4063) (FRL–9987–70), the
effective dates are corrected to be
September 14, 2018 to September 14,
2019.
FOR FURTHER INFORMATION CONTACT:
Michael L. Goodis, Director,
Registration Division (7505P), Office of
Pesticide Programs, Environmental
Protection Agency, 1200 Pennsylvania
Ave. NW, Washington, DC 20460–0001;
main telephone number: (703) 305–
7090; email address: RDFRNotices@
epa.gov.
SUPPLEMENTARY INFORMATION:
I. General Information
A. Does this action apply to me?
You may be potentially affected by
this action if you are an agricultural
producer, food manufacturer, or
pesticide manufacturer. The following
list of North American Industrial
Classification System (NAICS) codes is
not intended to be exhaustive, but rather
provides a guide to help readers
determine whether this document
applies to them. Potentially affected
entities may include:
• Crop production (NAICS code 111).
• Animal production (NAICS code
112).
• Food manufacturing (NAICS code
311).
• Pesticide manufacturing (NAICS
code 32532).
If you have any questions regarding
the applicability of this action to a
particular entity, consult the person
listed at the end of the emergency
exemption.
B. How can I get copies of this document
and other related information?
The docket for this action, identified
by docket identification (ID) number
EPA–HQ–OPP–2019–0050, is available
at https://www.regulations.gov or at the
Office of Pesticide Programs Regulatory
Public Docket (OPP Docket) in the
Environmental Protection Agency
Docket Center (EPA/DC), West William
Jefferson Clinton Bldg., Rm. 3334, 1301
Constitution Ave. NW, Washington, DC
20460–0001. The Public Reading Room
E:\FR\FM\17JNN1.SGM
17JNN1
]]>Agencies
[Federal Register Volume 84, Number 116 (Monday, June 17, 2019)]
[Notices]
[Pages 28039-28041]
From the Federal Register Online via the Government Publishing Office [www.gpo.gov]
[FR Doc No: 2019-12751]
-----------------------------------------------------------------------
DEPARTMENT OF ENERGY
Western Area Power Administration
2025 Resource Pool--Sierra Nevada Customer Service Region
AGENCY: Western Area Power Administration, DOE.
ACTION: Final power allocations from Central Valley and Washoe
Projects.
-----------------------------------------------------------------------
[[Page 28040]]
SUMMARY: Western Area Power Administration (WAPA) announces the final
2025 Resource Pool allocations from the Central Valley and Washoe
Projects under its 2025 Power Marketing Plan (Marketing Plan) for the
Sierra Nevada Customer Service Region (SNR). This notice includes a
summary of the comments received on WAPA's proposed 2025 Resource Pool
allocations and WAPA's responses.
DATES: The final 2025 Resource Pool allocations begin July 17, 2019.
FOR FURTHER INFORMATION CONTACT: Ms. Sandee Peebles, Public Utilities
Specialist, Western Area Power Administration, Sierra Nevada Customer
Service Region, 114 Parkshore Drive, Folsom, CA 95630-4710, (916) 353-
4454, [email protected].
SUPPLEMENTARY INFORMATION:
Background
WAPA published the Marketing Plan on August 15, 2017 (82 FR 38675)
to define how SNR will market hydropower from the Central Valley and
Washoe projects beginning January 1, 2025, and ending December 31,
2054. SNR's current marketing plan and contracts expire on December 31,
2024. As part of the Marketing Plan, SNR will withdraw 2 percent of the
existing marketable resource from existing customers, also known as
Base Resource, to create a resource pool. WAPA is marketing the 2-
percent resource pool to eligible preference entities.
WAPA published the Call for 2025 Resource Pool Applications in the
Federal Register on March 8, 2018 (83 FR 9851), and applications were
due by May 7, 2018. On July 13, 2018, WAPA extended the deadline to
file applications to August 13, 2018 (83 FR 32664). In response to the
Call for 2025 Resource Pool Applications, WAPA received 37
applications. After reviewing and considering the applications, WAPA
published the Proposed 2025 Resource Pool Allocations in the Federal
Register on February 12, 2019 (84 FR 3441) and opened a 30-day comment
period. The comment period ended on March 14, 2019. Summaries of the
comments received and WAPA's responses are provided below. After
considering all comments, WAPA has finalized the proposed power
allocations as discussed herein.
Responses to Comments Received on the Proposed 2025 Resource Pool
Allocations
During the comment period, WAPA received three letters commenting
on the proposed allocations from the 2025 Resource Pool. WAPA reviewed
and considered all comments made. Summaries of the comments and
responses are provided below.
Comment: All commenters expressed appreciation and support for the
proposed 2025 Resource Pool allocations.
Response: WAPA notes the comments of support for its 2025 Resource
Pool allocations.
Comment: All commenters requested additional allocations if
additional Base Resource becomes available.
Response: WAPA will allocate any additional available power, as
discussed below, in the Additional Base Resource section.
Final 2025 Resource Pool Allocations
The final 2025 Resource Pool allottees are listed below. The
allocations are expressed as percentages of the Base Resource with an
estimated megawatt-hour (MWh) amount of each allocation. The estimated
MWh for each allocation assumes an estimated average annual Base
Resource of 3,342,000 MWh and are rounded to the nearest MWh. The
actual amount of Base Resource a customer will receive will vary
hourly, daily, monthly, and annually depending on hydrology and other
constraints governing Central Valley Project operations. The final
allocations are as follows:
------------------------------------------------------------------------
Base Resource
Allottee allocation (%) Estimated MWh
------------------------------------------------------------------------
Army Air Force Exchange................. 0.03960 1,323
California State University, Sacramento. 0.01106 370
Cawelo Water District................... 0.00373 125
Eastside Power Authority................ 0.00362 121
Fallon, City of......................... 0.01988 664
Hoopa Valley Tribe...................... 0.00158 53
Kirkwood Meadows Public Utilities 0.03793 1,268
District...............................
Lower Tule Irrigation District.......... 0.00197 66
Merced Irrigation District.............. 0.10079 3,368
Modesto Irrigation District............. 0.30470 10,183
Monterey Bay Community Power............ 0.35347 11,813
Orange Cove Irrigation District......... 0.02382 796
Placer County Water Agency.............. 0.00394 132
Reclamation District 108................ 0.00072 24
Regents of the University of California. 0.14688 4,909
Roseville, City of...................... 0.00979 327
Sacramento Municipal Utility District... 0.01735 580
Santa Clara Water District.............. 0.00365 122
Silicon Valley Clean Energy Authority... 0.32467 10,850
Sonoma County Water Agency.............. 0.00360 120
Stockton, Port of....................... 0.01155 386
Truckee Donner Public Utility District.. 0.03716 1,242
Turlock Irrigation District............. 0.32956 11,014
University of California, Davis......... 0.01949 651
Water Resources, California Department 0.14398 4,812
of.....................................
Woodland Davis Clean Water Agency....... 0.04371 1,461
Zone 7, Alameda County Flood Control & 0.00180 60
Water Conservation District............
-------------------------------
2.00000 66,840
------------------------------------------------------------------------
[[Page 28041]]
Additional Base Resource
Under the Marketing Plan, there may be future opportunities for
entities to receive a Base Resource allocation from WAPA, for instance:
1. If an allocation is withdrawn because an allottee or an existing
customer is unable to execute a contract or secure transmission
arrangements for the delivery of power by the prescribed dates.
2. A customer surrenders an allocation.
3. An allottee's or existing customer's base resource allocation is
greater than its need.
If additional base resource is available for reallocation prior to
the creation of the next resource pool in 2040, WAPA, at its discretion
and sole determination, reserves the right to reallocate the additional
base resource through bilateral negotiations. WAPA also reserves the
right to offer any additional base resource to (1) eligible entities
who submitted applications during the 2025 Call for Applications, (2)
existing customers, (3) new preference entities, or (4) any entity on a
short-term basis.
Contracting Process
SNR will offer existing customers 98 percent of their current base
resource allocations. For existing customers who received a resource
pool allocation, the additional allocation will be included with their
remaining base resource allocations.
After the effective date of this notice, SNR will begin the
contracting process. WAPA will send all existing customers and new
allottees a pro forma electric service contract to purchase the base
resource. All existing customers and new allottees must execute and
return SNR's pro forma electric service contract within 6 months of the
date of WAPA's letter submitting the pro forma contract, unless
otherwise agreed to in writing by SNR. SNR reserves the right to
withdraw and reallocate any power allocation if an existing customer or
allottee does not execute the electric service contract within the 6-
month period. The date of initial service under these contracts is
January 1, 2025, and these contracts will remain in effect until
midnight of December 31, 2054.
SNR solely determines the terms, conditions, rates, or charges of
its power contracts. SNR will work with existing customers and new
allottees to develop customized products, if requested, to meet their
needs. Each existing customer and new allottee is responsible for
obtaining transmission arrangements for delivery of power to its load.
Upon request, SNR may assist in obtaining transmission arrangements for
delivery of power; however, it is the customer's or allottee's ultimate
responsibility to secure necessary transmission arrangements.
Authorities
The Marketing Plan, published in the Federal Register (82 FR 38675)
on August 15, 2017, was established under the Department of Energy
Organization Act (42 U.S.C. 7101 et seq.); the Reclamation Act of June
17, 1902 (Pub. L. 57-161, 32 Stat. 388), as amended and supplemented by
subsequent enactments, particularly section 9(c) of the Reclamation
Project Act of 1939 (43 U.S.C. 485h(c)); and other acts specifically
applicable to the projects involved. Allocating power from the resource
pool falls within the Marketing Plan and is covered by this authority.
Regulatory Procedure Requirements
Environmental Compliance
In accordance with DOE National Environmental Policy Act
Implementing Procedures (10 CFR 1021), WAPA has determined this action
falls within a class of action B4.1 contracts, policies, marketing, and
allocation plans for electric power, in Appendix B to Subpart D to Part
1021--Categorical Exclusion Applicable to Specific Agency Actions.
Determination Under Executive Order 12866
WAPA 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 requred.
Dated: June 4, 2019.
Mark A. Gabriel,
Administrator.
[FR Doc. 2019-12751 Filed 6-14-19; 8:45 am]
BILLING CODE 6450-01-P
