33148 Federal Register / Vol. 87, No. 105 / Wednesday, June 1, 2022 / Notices 

1The determination was done in compliance with 

NEPA (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). 

Olmsted Project, as well as the other 

participating projects of CRSP, in 

accordance with the following Acts of 

Congress: Reclamation Act of June 17, 

1902 (Pub. L. 57–161) (32 Stat. 388), 

Revision of the Reclamation Act of 

August 4, 1939 (Pub. L. 76–260) (53 

Stat. 1187), Colorado River Storage 

Project Act of April 11, 1956 (Pub. L. 

84–485) (70 Stat. 105), Department of 

Energy Organization Act of August 4, 

1977 (Pub. L. 95–91) (91 Stat. 565), 

Energy Policy Act of October 30, 1992 

(Pub. L. 102–575) (106 Stat. 4600, 4605), 

as amended. 

Availability of Information 

Documents developed or retained by 

WAPA during this public process will 

be available on WAPA’s website, by 

appointment, for inspection and 

copying at the CRSP MC at the 

ADDRESSES Section above. Written 

comments received as part of the 

Proposed 2025 Olmsted Power 

Marketing Plan formal public process 

will be available for viewing on CRSP’s 

website. 

Regulatory Procedure Requirements 

A. Review Under the National 

Environmental Policy Act (NEPA) 

WAPA has determined that this 

proposed action fits within the 

categorical exclusion listed in appendix 

B to subpart D of 10 CFR part 1021 (B4.1 

Contracts, policies, and marketing and 

allocation plans for electric power). 

Categorically excluded projects and 

activities do not require preparation of 

either an environmental impact 

statement or an environmental 

assessment.1 Specifically, WAPA has 

determined that this rulemaking is 

consistent with activities identified in 

part B4, Categorical Exclusions 

Applicable to Specific Agency Actions 

(see 10 CFR part 1021, appendix B to 

subpart D, part B4). A copy of the 

categorical exclusion determination is 

available on the CRSP website at: 

https://www.wapa.gov/regions/CRSP/ 

environment/Pages/environment.aspx. 

B. Review Under the Regulatory 

Flexibility Act 

The Regulatory Flexibility Act of 1980 

(RFA), 5 U.S.C. 601 et seq., requires a 

federal agency to perform a regulatory 

flexibility analysis whenever the agency 

is required by law to publish a general 

notice of proposed rulemaking for any 

proposed rule, unless the agency can 

certify that the rule will not have a 

significant economic impact on a 

substantial number of small entities. For 

purposes of the RFA, a ‘‘rule’’ does not 

include ‘‘a rule of particular 

applicability relating to rates [and] 

services . . . or to valuations, costs or 

accounting, or practices relating to such 

rates [and] services . . .’’ 5 U.S.C. 601. 

WAPA has determined that this action 

relates to services offered by WAPA 

and, therefore, is not a rule within the 

purview of the RFA. 

C. 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 required. 

D. Review Under Paperwork Reduction 

Act 

In accordance with the Paperwork 

Reduction Act (44 U.S.C. 3501, et seq.), 

WAPA has received approval from the 

Office of Management and Budget to 

collect applicant data, under OMB 

control number 1910–5136. 

Signing Authority 

This document of the Department of 

Energy was signed on [DATE], by 

Tracey A. LeBeau, Administrator, 

Western Area Power Administration, 

pursuant to delegated authority from the 

Secretary of Energy. That document, 

with the original signature and date, is 

maintained by DOE. For administrative 

purposes only, and in compliance with 

requirements of the Office of the Federal 

Register, the undersigned DOE Federal 

Register Liaison Officer has been 

authorized to sign and submit the 

document in electronic format for 

publication, as an official document of 

the Department of Energy. This 

administrative process in no way alters 

the legal effect of this document upon 

publication in the Federal Register. 

Signed in Washington, DC, on May 24, 

2022. 

Treena V. Garrett, 

Federal Register Liaison Officer, U.S. 

Department of Energy. 

[FR Doc. 2022–11475 Filed 5–31–22; 8:45 am] 

BILLING CODE 6450–01–P 

DEPARTMENT OF ENERGY 

Western Area Power Administration 

Proposed 2025 Provo River Project 

Marketing Plan 

AGENCY: Western Area Power 

Administration, DOE. 

ACTION: Notice of proposed 2025 Provo 

River project marketing plan and 

announcement of public information 

and comment forum. 

SUMMARY: Western Area Power 

Administration (WAPA), a federal 

Power Marketing Administration of the 

Department of Energy (DOE), is seeking 

comments on this proposed 2025 Provo 

River Project (PRP) Marketing Plan, 

including the general power marketing 

criteria to be used as the basis for 

marketing the hydroelectric generation 

of the PRP. The current PRP Marketing 

Plan expires September 30, 2024, and 

the proposed 2025 PRP Marketing Plan 

would take effect October 1, 2024. 

DATES: The public comment period on 

the Proposed 2025 PRP Marketing Plan 

begins June 1, 2022 and ends August 30, 

2022. To be assured of consideration, 

WAPA must receive all written 

comments by the end of the comment 

period. 

WAPA will hold a virtual public 

information forum about this proposed 

marketing plan on Thursday, June 28, 

2022, from 9:30 a.m. to 12:00 p.m. MDT. 

The virtual public comment forum is 

scheduled the same day, Thursday, June 

28, 2022, beginning at 1:00 p.m. MDT 

and concluding when comments are 

complete, or no later than 4:00 p.m. 

MDT. Due to the COVID–19 pandemic, 

neither the public information nor 

comment forums will be held in-person. 

Information on the virtual meeting may 

be found on the Colorado River Storage 

Project (CRSP) website at: https://

www.wapa.gov/regions/CRSP/

PowerMarketing/Pages/powermarketing.aspx. WAPA will post 

webinar and dial in information at this 

link 14 days before the scheduled 

forums. 

ADDRESSES: Submit written comments 

about this proposed marketing plan to: 

Mr. Rodney Bailey, Acting CRSP 

Manager, CRSP Management Center 

(MC), Western Area Power 

Administration, 1800 South Rio Grande 

Avenue, Montrose, CO 81401. 

Comments also may be emailed to 

Provo-Marketing@wapa.gov or be faxed 

to 970–240–6282. All documentation 

developed or retained by WAPA for the 

purpose of developing the proposed 

marketing plan is available for 

inspection and copying at the CRSP MC. 

FOR FURTHER INFORMATION CONTACT: Mr. 

Randolph Manion, CRSP Contracts and 

Energy Services Manager, Manion@

wapa.gov, 720–201–3285. Written 

requests for information should be 

mailed to CRSP MC at the ADDRESSES

section. 


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Federal Register / Vol. 87, No. 105 / Wednesday, June 1, 2022 / Notices 33149 

SUPPLEMENTARY INFORMATION: WAPA is 

responsible for marketing power from 

the PRP, which is done independently 

from the other projects marketed by 

WAPA’s CRSP, including the Salt Lake 

City Area Integrated Projects (SLCA/IP), 

Olmsted Project, and the FalconAmistad Project. In addition to 

marketing power from the PRP and 

other projects, WAPA’s CRSP operates 

approximately 2,316 miles of 

transmission line and associated 

infrastructure related to these federal 

hydroelectric projects across Arizona, 

New Mexico, Colorado, Utah, and 

Wyoming. This Federal Register notice 

formally initiates WAPA’s public 

process and request for public 

comments on the proposed 2025 PRP 

Marketing Plan. WAPA will prepare and 

publish the final 2025 PRP Marketing 

Plan after public comments on the 

proposed marketing plan are 

considered. This Federal Register notice 

is not a call for applications. A call for 

applications from those interested in an 

allocation of PRP power will occur in a 

future Federal Register notice. 

The PRP is a small water development 

project, with a powerplant, in northern 

Utah. It was authorized by President 

Franklin D. Roosevelt, in part, as a 

response to the Great Depression and a 

severe drought that devasted Utah’s 

agriculture and threatened municipal 

water supplies in the 1930s. PRP’s 

primary function is to provide 

irrigation, municipal, and industrial 

water to users in Salt Lake and Utah 

Counties, Utah. The Department of the 

Interior, Bureau of Reclamation 

(Reclamation) finished construction of 

the Deer Creek Dam in 1938 and the 

Deer Creek Powerplant in 1958, which 

included two 2.475-megawatt 

generators. On June 27, 1936, 

Reclamation signed contract number Ilr874 making the Provo River Water 

Users’ Association (PRWUA) the 

operator of the dam and responsible for 

repayment of the PRP. The initial 

investment in the power facilities was 

repaid in 1984 but there are ongoing 

costs associated with operation, 

maintenance, and replacement (OM&R) 

of equipment. Surplus power revenues 

may be used to aid the repayment of the 

PRP irrigation investment. 

Between October 15 and April 15, 

water may be diverted from the adjacent 

Weber River Basin into the Provo River 

and stored in Deer Creek Reservoir for 

irrigation purposes pursuant to the 

terms of the 1938 contract number Ilr– 

1082 between the PRWUA, PacifiCorp 

(formerly Utah Power and Light 

Company), and Reclamation, among 

others. The diversion creates a loss of 

power generation at the Weber 

Powerplant on the Weber River, 

downstream from the diversion. As a 

result, PacifiCorp, the owner of the 

Weber Powerplant, is reimbursed for its 

winter energy losses with PRP energy 

(Weber/Provo Water Exchange). During 

this winter period, PRP generation 

above the reimbursement amount is sold 

to WAPA’s CRSP as non-firm surplus 

energy; during the summer period, PRP 

generation is sold to WAPA’s CRSP as 

firm energy. 

Current Marketing Plan Background 

Under the Final Provo River Project 

Marketing Plan published in the Federal 

Register November 21, 1994 (59 FR 

60007), WAPA markets PRP power and 

energy, independent from the SLCA/IP, 

to eight preference entities including 

Heber City, Lehi, Springville, 

Strawberry Electric Service District, and 

Payson through Intermountain 

Consumers Power Association (in 1995, 

WAPA’s contract with Intermountain 

Consumers Power Association was 

transferred to Utah Associated 

Municipal Power Systems); and Provo, 

Salem, and Spanish Fork through the 

Utah Municipal Power Agency, 

hereinafter referred to as Customers. 

Under the current Marketing Plan, 

PRP is a ‘‘take all, pay all’’ contractual 

arrangement, i.e., the annual revenue 

requirement is not dependent upon the 

amount of marketable energy available 

each year. Customers with an allocation 

pay their share of all PRP annual OM&R 

costs, including a separate annual 

payment to Reclamation for the PRP 

irrigation investments, in return for 

receiving all marketable energy 

produced by PRP each year. For 

additional information, see the February 

14, 2020 Federal Register Notice 

announcing the Provo River Project— 

Rate Order No. WAPA–189, Provisional 

Formula Rate PR–2, effective April 1, 

2020, through March 31, 2025, (85 FR 

8583) (‘‘WAPA–189’’). 

Proposed 2025 Provo River Project 

General Power Marketing Criteria 

In the proposed 2025 PRP Marketing 

Plan, WAPA proposes to offer a resource 

extension to existing Customers, and to 

offer a portion of the resource to new 

applicants under the following general 

marketing criteria. 

A. Marketing Area: Due to the 

relatively small size of the resource and 

its operating characteristics, eligible 

applicants must be located within Utah 

and Wasatch counties, Utah. 

B. Resource Extension and Resource 

Pool Allocations: WAPA proposes to 

provide 95 percent of its available 

energy resource to existing Customers 

and to establish a resource pool up to 

5 percent for new eligible applicants. 

WAPA will take into consideration all 

existing federal hydropower allocations 

an applicant is currently receiving when 

determining each allocation. Eligible 

applicants who receive an allocation 

from the Deer Creek Powerplant will 

receive a percentage of available annual 

winter (October–March) and summer 

(April–September) generation rather 

than fixed quantities of energy; 

percentages will be solely determined 

by WAPA. Historically, marketable 

energy has averaged 23,000,000 

kilowatt-hours (kWh), with 15,000,000 

kWh generated during the summer 

months, and the remaining 8,000,000 

kWh from winter surplus energy. Most 

recently, PRP’s five-year net generation 

average is 23,500,000 kWh. 

C. Preference Entities: Municipalities, 

rural electric cooperatives, and political 

subdivisions including irrigation or 

other districts, and other governmental 

organizations that have electric utility 

status by October 1, 2023, and federally 

recognized Native American tribes are 

all preference entities in accordance 

with section 9(c) of the Reclamation 

Project Act of 1939, as amended (43 

U.S.C. 485h(c)). A Native American 

applicant must be an ‘‘Indian Tribe’’ as 

that term is defined in section 4 of the 

Indian Self Determination and 

Education Assistance Act, as amended 

(25 U.S.C. 5304). ‘‘Electric utility status’’ 

means that the entity has responsibility 

to meet load growth, has a distribution 

system, and is ready, willing, and able 

to purchase federal power from WAPA 

on a wholesale basis. 

D. Ready, Willing, and Able: Eligible 

applicants must be ready, willing, and 

able to receive and distribute or use 

energy from WAPA. ‘‘Ready, willing, 

and able’’ means the applicant has the 

facilities needed for the receipt of power 

or has made the necessary arrangements 

for transmission and/or distribution 

service, and its power supply contracts 

with third parties permit the delivery of 

WAPA’s power. 

E. Eligible Applicants: Eligible 

applicants must qualify as preference 

entities, in accordance with section 9(c) 

of the Reclamation Project Act of 1939, 

43 U.S.C. 485h(c). WAPA will provide 

allocations only to preference entities in 

the marketing area. WAPA, through a 

separate public process, will determine 

the amount of energy, if any, to allocate 

in accordance with the marketing 

criteria and administrative discretion 

under Reclamation Law (e.g., 

Reclamation Act of 1902, 32 Stat. 388, 

as amended). 

F. Contract Obligations: Eligible 

applicants that receive an allocation 

must execute electric service contracts 


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33150 Federal Register / Vol. 87, No. 105 / Wednesday, June 1, 2022 / Notices 

1The determination was done in compliance with 

NEPA (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). 

within 6 months of receiving a contract 

offer from WAPA, unless WAPA agrees 

otherwise in writing. Furthermore, the 

applicant must comply with all terms 

and conditions stated within that 

contract, including scheduling, 

accounting, and billing procedures; 

Energy Planning and Management 

Program requirements; General Power 

Contract Provisions; and power factor, 

among others. 

G. Separate Contractual 

Arrangements with PacifiCorp: Eligible 

applicants that receive an allocation 

must execute a separate multi-party 

agreement among WAPA, Reclamation, 

Central Utah Water Conservation 

District, PRWUA, and PacifiCorp to 

ensure repayment of energy to 

PacifiCorp for the loss of power 

generation due to the Weber/Provo 

Water Exchange. 

H. Contract Term: The term of the 

contract will be 10 years. Resource 

extensions and new allocations would 

begin on October 1, 2024, and remain in 

effect through September 30, 2034. 

However, the contract will 

automatically renew for up to two 

additional 5-year terms, commencing on 

October 1, 2034, and October 1, 2039, 

respectively, unless no later than 3 years 

before the beginning of an extension (by 

October 1, 2031, and October 1, 2036, 

respectively), any party to the contract 

gives written notice not to renew. If 

such notice is given, the automatic 

renewal option will be revoked, and all 

contracts will expire on September 30, 

2034, or September 30, 2039, 

respectively. 

I. Delivery Point: PRP is electrically 

interconnected to PacifiCorp’s 138- 

kilovolt (kV) transmission system 

(PacifiCorp’s System). Eligible 

applicants taking delivery of power 

from WAPA must do so at the 

PacifiCorp System 138-kV Hale 

Powerplant Switchyard, South Provo 

Tap, or Spanish Fork Substation. Costs 

for transmission will be paid by the 

eligible applicants through appropriate 

contractual arrangements. 

J. Transmission Beyond Delivery 

Point: Any associated transformation/ 

transmission beyond the PacifiCorp 

System 138-kV Hale Powerplant 

Switchyard, South Provo Tap, or 

Spanish Fork Substation is the sole 

responsibility of the eligible applicants. 

Eligible applicants that receive an 

allocation must have the necessary 

arrangements for transmission and/or 

distribution service in place by October 

1, 2023. 

K. Regional Transmission 

Organization: Should PacifiCorp, as the 

balancing authority operator in the PRP 

area, join a full electricity market (e.g., 

a Regional Transmission Organization 

and/or an Independent System 

Operator), and in joining that market 

create an unintended delivery point or 

point of receipt financial impact to the 

PRP and/or other unintended financial 

impacts, such financial impacts will be 

included as part of the PRP operation 

expenses, and WAPA will work with 

the Customers in good faith in an 

attempt to minimize those financial 

impacts. 

L. Rates and Payment: PRP is a ‘‘take 

all, pay all’’ project. This means the 

annual revenue requirement does not 

depend on the amount of energy 

available each year. Each eligible 

applicant that receives an allocation 

will receive a proportional share of the 

energy and will annually pay a 

proportional share of the OM&R 

expenses, including a separate annual 

payment to Reclamation for the PRP 

irrigation investments, in 12 monthly 

installments. For additional 

information, see Rate Order No. WAPA– 

189. 

Legal Authority 

WAPA is responsible for marketing 

the federal power produced by the PRP, 

as well as the other participating 

projects of CRSP, in accordance with the 

following Acts of Congress: Reclamation 

Act of June 17, 1902 (Pub. L. 57–161) 

(32 Stat. 388), Provo River Project of 

December 5, 1924 (43 Stat. 701), 

Revision of the Reclamation Act of 

August 4, 1939 (Pub. L. 76–260) (53 

Stat. 1187), Colorado River Storage 

Project Act of April 11, 1956 (Pub. L. 

84–485) (70 Stat. 105), Department of 

Energy Organization Act of August 4, 

1977 (Pub. L. 95–91) (91 Stat. 565), as 

amended. 

Availability of Information 

Documents developed or retained by 

WAPA during this public process will 

be available on CRSP’s website, by 

appointment, for inspection and 

copying at the CRSP MC at the 

ADDRESSES Section above. Written 

comments received as part of the 

Proposed 2025 PRP Marketing Plan 

formal public process will be available 

for viewing on CRSP’s website. 

Regulatory Procedure Requirements 

A. Review Under the National 

Environmental Policy Act (NEPA) 

WAPA has determined that this 

proposed action fits within the 

categorical exclusion listed in appendix 

B to subpart D of 10 CFR part 1021 (B4.1 

Contracts, policies, and marketing and 

allocation plans for electric power). 

Categorically excluded projects and 

activities do not require preparation of 

either an environmental impact 

statement or an environmental 

assessment.1 Specifically, WAPA has 

determined that this rulemaking is 

consistent with activities identified in 

part B4, Categorical Exclusions 

Applicable to Specific Agency Actions 

(see 10 CFR part 1021, appendix B to 

subpart D, part B4). A copy of the 

categorical exclusion determination is 

available on CRSP’s website at: https:// 

www.wapa.gov/regions/CRSP/ 

environment/Pages/environment.aspx. 

B. Review Under the Regulatory 

Flexibility Act 

The Regulatory Flexibility Act of 1980 

(RFA) 5 U.S.C. 601 et seq., requires a 

federal agency to perform a regulatory 

flexibility analysis whenever the agency 

is required by law to publish a general 

notice of proposed rulemaking for any 

proposed rule, unless the agency can 

certify that the rule will not have a 

significant economic impact on a 

substantial number of small entities. For 

purposes of the RFA, a ‘‘rule’’ does not 

include ‘‘a rule of particular 

applicability relating to rates [and] 

services . . . or to valuations, costs or 

accounting, or practices relating to such 

rates [and] services . . .’’ 5 U.S.C. 601. 

WAPA has determined that this action 

relates to services offered by WAPA 

and, therefore, is not a rule within the 

purview of the RFA. 

C. 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 required. 

D. Review Under Paperwork Reduction 

Act 

In accordance with the Paperwork 

Reduction Act (44 U.S.C. 3501, et seq.), 

WAPA has received approval from the 

Office of Management and Budget to 

collect applicant profile data, under 

OMB control number 1910–5136. 

Signing Authority 

This document of the Department of 

Energy was signed on [DATE], by 

Tracey A. LeBeau, Administrator, 

Western Area Power Administration, 

pursuant to delegated authority from the 

Secretary of Energy. That document, 

with the original signature and date, is 


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Federal Register / Vol. 87, No. 105 / Wednesday, June 1, 2022 / Notices 33151 

maintained by DOE. For administrative 

purposes only, and in compliance with 

requirements of the Office of the Federal 

Register, the undersigned DOE Federal 

Register Liaison Officer has been 

authorized to sign and submit the 

document in electronic format for 

publication, as an official document of 

the Department of Energy. This 

administrative process in no way alters 

the legal effect of this document upon 

publication in the Federal Register. 

Signed in Washington, DC, on May 24, 

2022. 

Treena V. Garrett, 

Federal Register Liaison Officer, U.S. 

Department of Energy. 

[FR Doc. 2022–11476 Filed 5–31–22; 8:45 am] 

BILLING CODE 6450–01–P 

ENVIRONMENTAL PROTECTION 

AGENCY 

[FRL–9535–02–OA] 

Local Government Advisory 

Committee (LGAC) and Small 

Communities Advisory Subcommittee 

(SCAS) Meeting 

AGENCY: Environmental Protection 

Agency (EPA). 

ACTION: Notification of public meeting. 

SUMMARY: Pursuant to the Federal 

Advisory Committee Act (FACA), EPA 

herby provides notice of a meeting for 

the Local Government Advisory 

Committee (LGAC) and its Small 

Communities Advisory Subcommittee 

(SCAS) on the date and time described 

below. This meeting will be open to the 

public. For information on public 

attendance and participation, please see 

the registration information under 

SUPPLEMENTARY INFORMATION. 

DATES: The LGAC will have a hybrid 

virtual/in-person meeting June 23rd, 

2022, starting at 8:30 a.m. through 3:00 

p.m. Eastern Daylight Time. The public 

comment period will be 2:15–2:30 p.m. 

The SCAS will have a hybrid virtual/ 

in-person meeting June 24th, 2022, 

starting at 8:30 a.m. through 12:00 p.m. 

Eastern Daylight Time. The public 

comment period will be 9:45 a.m.–9:55 

a.m. 

The LGAC and SCAS will also have 

a joint hybrid virtual/in-person meeting 

June 24th, 2022, starting at 10:30 a.m. 

through 12:00 p.m. Eastern Daylight 

Time. 

FOR FURTHER INFORMATION CONTACT: 

Paige Lieberman, Designated Federal 

Officer (DFO), at LGAC@epa.gov or 202– 

564–9957 

Information on Accessibility: For 

information on access or services for 

individuals requiring accessibility 

accommodations, please contact Paige 

Lieberman by email at LGAC@epa.gov. 

To request accommodation, please do so 

five (5) business days prior to the 

meeting, to give EPA as much time as 

possible to process your request. 

SUPPLEMENTARY INFORMATION: These 

meetings will be held at EPA’s Offices 

in Washington, DC, at 1200 Constitution 

Ave. NW. Virtual participation via 

Zoom will also be available. The EPA 

has charged the LGAC and SCAS with 

the following questions, which will be 

discussed at these meetings. Drafts of 

the recommendations will be available 

prior to the meeting for all registered 

attendees. The joint meeting of the 

SCAS and LGAC on June 24 will 

include a panel discussion on technical 

assistance with several 

nongovernmental organizations. 

Current Charge Questions for Local 

Government Advisory Committee 

(LGAC) 

1. The Bipartisan Infrastructure Law 

is delivering more than $50 billion to 

EPA to improve our nation’s drinking 

water, wastewater, and stormwater 

infrastructure. As EPA works to 

implement this law, the LGAC is 

providing input on: 

• Are there tools, resources, or 

technical assistance that EPA can 

provide to help local governments 

access BIL funding to upgrade their 

water and wastewater infrastructure? 

• How can EPA work with the LGAC 

to educate, engage, and celebrate local 

successes from BIL implementation? 

2. As EPA implements the Bipartisan 

Infrastructure Law, how can we do so in 

a way that supports the 

Administration’s priorities of tackling 

the climate crisis? 

• Is there specific technical assistance 

that EPA should offer local governments 

to ensure they plan for, develop and 

build infrastructure that supports 

multiple community goals, including 

improving environmental and economic 

outcomes, supporting equity and 

environmental justice, and increasing 

communities’ abilities to create climate 

resilience? 

3. In October 2021, EPA announced a 

PFAS Strategic Roadmap, which laid 

out a whole-of-agency approach to 

addressing PFAS. This Roadmap 

includes several regulatory and policy 

actions regarding PFAS contamination. 

Given that these processes can take 

several years, how can EPA support 

local governments to address PFAS 

contamination in the interim? 

4. How can EPA meet the needs and 

environmental priorities of 

overburdened communities while also 

strengthening local government capacity 

to provide ongoing environmental 

protections in partnership with the 

states and EPA? 

Current Charge Questions for Small 

Communities Advisory Subcommittee 

(SCAS) 

1. As EPA works to implement the 

BIL, how can the Agency best: 

• Support clean and sustainable air, 

water, and land priorities for small and 

rural communities. 

• Support capacity needs/ 

advancement for small and rural 

communities. 

• Ensure long-lasting communication 

between EPA and local officials from 

small and rural communities. 

• Ensure small communities are 

positioned to benefit from this 

generational investment in 

environmental infrastructure. 

Registration: All interested persons 

are invited to attend and participate, 

either in person or virtually. The LGAC 

will hear comments from the public 

from 2:15–2:30 p.m. (EDT) on June 23rd. 

The SCAS will hear comments from the 

public 9:45–9:55 a.m. (EDT) on June 

24th. Individuals or organizations 

wishing to address the Committee or 

Subcommittee will be allowed a 

maximum of five (5) minutes to present 

their point of view. Also, written 

comments should be submitted 

electronically to LGAC@epa.gov for the 

LGAC and SCAS. Please contact the 

DFO at the email listed under FOR

FURTHER INFORMATION CONTACT to 

schedule a time on the agenda by June 

16, 2022. Time will be allotted on a 

first-come first-served basis, and the 

total period for comments may be 

extended if the number of requests for 

appearances requires it. 

The agenda and other supportive 

meeting materials will be available 

online at https://www.epa.gov/ocir/ 

local-government-advisory-committeelgac and can be obtained by written 

request to the DFO. In the event of 

cancellation for unforeseen 

circumstances, please contact the DFO 

or check the website above for 

reschedule information. 

All in-person meeting attendees must 

comply with current Agency COVID–19 

protocols. This information will be 

shared with all registered attendees 

prior to the meeting. 

Dated: May 25, 2022. 

Jack Bowles, 

Director, State and Local Relations, Office 

of Congressional and Intergovernmental 

Relations. 

[FR Doc. 2022–11705 Filed 5–31–22; 8:45 am] 

BILLING CODE 6560–50–P 


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