(b) INCLUSION
IN PORTAL.—The Secretary shall 
make public through the searchable online portal estab-
lished under this section each scorecard, together with the 
underlying data associated with each scorecard, that is 
submitted to the Secretary under this Act. 
SEC. 5. SCORECARD IMPROVEMENT. 
(a) TECHNICAL CONFERENCES.—The Commission 
shall hold public technical conferences not less often than 
once every 3 years to solicit stakeholder feedback on— 
(1) the effectiveness of scorecard metrics in 
conveying the performance of a given reporting enti-
ty; 
(2) the sufficiency and quality of the data dis-
closed in scorecards; 
(3) the alignment of scorecards with Federal 
and State priorities, including affordability, reli-
ability, and congestion reduction of transmitted elec-
tricity; and 
(4) opportunities to refine metrics in light of 
emerging technologies, grid conditions, and energy 
markets. 
(b) STAKEHOLDER ADVISORY GROUPS.—For pur-
poses of a rulemaking under section 3 and each technical 
conference held under subsection (a), the Commission 
shall convene a stakeholder advisory group to provide ad-
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vice to the Commission. Each such stakeholder advisory 
group shall be composed of 17 members, as follows: 
(1) 2 members representing State public utility 
commissions. 
(2) 2 members representing covered trans-
mission owners. 
(3) 2 members representing independent power 
producers. 
(4) 2 members representing Regional Trans-
mission Organizations and Independent System Op-
erators. 
(5) 1 member representing the Electric Reli-
ability Organization. 
(6) 2 members representing transmission plan-
ning entities. 
(7) 2 members representing ratepayer advocacy 
organizations, each of whom shall be employed by, 
or formally designated by, an organization the pri-
mary mission of which is the representation of resi-
dential, commercial, or industrial ratepayers in regu-
latory or ratemaking proceedings before State or 
Federal authorities. 
(8) 2 members with expertise in energy data 
systems, grid modeling, or electricity market ana-
lytics, each of whom shall possess significant profes-
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sional experience or academic qualifications, rep-
resenting industry, independent analytics firms, or 
academic or research institutions, including the Na-
tional Laboratories. 
(9) 2 members with expertise in energy systems 
performance, representing academic or research in-
stitutions, including the National Laboratories. 
(c) RESPONSE REQUIRED.—Not later than 60 days 
after receiving any advice from a stakeholder group con-
vened under subsection (b), the Commission shall respond 
in writing to such advice. 
SEC. 6. DEFINITIONS. 
In this Act: 
(1) ADMINISTRATOR.—The term ‘‘Adminis-
trator’’ means the Administrator of the Energy In-
formation Administration of the Department of En-
ergy. 
(2) COMMISSION.—The term ‘‘Commission’’ 
means the Federal Energy Regulatory Commission. 
(3) COVERED
TRANSMISSION
OWNER.—The 
term ‘‘covered transmission owner’’ means any enti-
ty, other than an Independent System Operator, Re-
gional Transmission Organization, or transmission 
planning entity, that— 
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(A) owns, operates, or controls trans-
mission facilities that are part of, or connected 
to the bulk-power system; 
(B) provides, or is capable of providing, 
transmission service for the movement of elec-
tric energy, whether in interstate or intrastate 
commerce; and 
(C) if the entity owns, operates, or controls 
transmission facilities that are not part of, or 
connected to, the bulk-power system, the total 
transmission capacity under peak demand con-
ditions of all transmission facilities owned, op-
erated, or controlled by the entity is 100 
megawatts or greater. 
(4) FEDERAL POWER ACT TERMS.— 
(A) BULK-POWER
SYSTEM; 
ERO.—The 
terms ‘‘bulk-power system’’ and ‘‘Electric Reli-
ability Organization’’ have the meanings given 
those terms in section 215 of the Federal 
Power Act (16 U.S.C. 824o). 
(B) ISO; RTO; TRANSMITTING UTILITY.— 
The terms ‘‘Independent System Operator’’, 
‘‘ISO’’, ‘‘Regional Transmission Organization’’, 
‘‘RTO’’, and ‘‘transmitting utility’’ have the 
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meanings given those terms in section 3 of the 
Federal Power Act (16 U.S.C. 796). 
(5) GRID-ENHANCING TECHNOLOGY.—The term 
‘‘grid-enhancing technology’’ means any technology 
the Commission determines materially improves 
transfer capacity or interconnection efficiency, or re-
duces technical losses, without relying on traditional 
wires-based transmission expansion, which shall in-
clude— 
(A) dynamic line rating systems; 
(B) advanced power flow control devices; 
(C) topology optimization tools and soft-
ware-based reconfiguration technologies; 
(D) real-time monitoring and sensing 
equipment that improves line utilization or visi-
bility; and 
(E) transformer upgrades, advanced trans-
mission technologies, or reactive power equip-
ment. 
(6) INTERREGIONAL INTERCONNECTION.—The 
term ‘‘interregional interconnection’’ means a trans-
mission facility or interconnection project that en-
ables the transfer of electric energy between two or 
more transmission planning regions, including con-
nections between any of the Western Interconnec-
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tion, the Eastern Interconnection, and the Electric 
Reliability Council of Texas. 
(7) REPORTING ENTITY.—The term ‘‘reporting 
entity’’ means an entity required to submit a score-
card under this Act. 
(8) SCORECARD.—The term ‘‘scorecard’’ means 
a report required to be submitted by a covered 
transmission owner, Independent System Operator, 
Regional Transmission Organization, or trans-
mission planning entity pursuant to section 3. 
(9) SEAM.—The term ‘‘seam’’ means a bound-
ary or interface between neighboring transmission 
systems or grid operators. 
(10) 
SECRETARY.—The 
term 
‘‘Secretary’’ 
means the Secretary of Energy. 
(11) TRANSMISSION
PLANNING
ENTITY.—The 
term ‘‘transmission planning entity’’ means an enti-
ty, other than a RTO or an ISO, that is responsible 
for planning for the deployment of electric trans-
mission for a transmission planning region. 
(12) TRANSMISSION
PLANNING
REGION.—The 
term ‘‘transmission planning region’’ means a geo-
graphic area determined by the Commission to sat-
isfy the requirements for the scope of regional trans-
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mission planning, as established in or in compliance 
with the following orders issued by the Commission: 
(A) ‘‘Transmission Planning and Cost Al-
location by Transmission Owning and Oper-
ating Public Utilities’’ published in the Federal 
Register on October 24, 2012 (77 Fed. Reg. 
64890). 
(B) ‘‘Building for the Future Through 
Electric Regional Transmission Planning and 
Cost Allocation’’ published in the Federal Reg-
ister on June 11, 2024 (89 Fed. Reg. 49280). 
Æ 
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