I 
119TH CONGRESS 
1ST SESSION H. R. 6176 
To require standardized performance reporting for entities engaged in elec-
tricity transmission to improve transparency, accountability, and grid 
outcomes, and for other purposes. 
IN THE HOUSE OF REPRESENTATIVES 
NOVEMBER 20, 2025 
Mr. CASTEN (for himself, Mr. MULLIN, Mr. HUFFMAN, Mr. SUBRAMANYAM, 
Mr. QUIGLEY, Mr. GARAMENDI, Ms. CASTOR of Florida, Mr. MOULTON, 
Mr. FOSTER, Mr. LEVIN, and Mr. CARSON) introduced the following bill; 
which was referred to the Committee on Energy and Commerce 
A BILL 
To require standardized performance reporting for entities 
engaged in electricity transmission to improve trans-
parency, accountability, and grid outcomes, and for other 
purposes. 
Be it enacted by the Senate and House of Representa-
tives of the United States of America in Congress assembled, 
SECTION 1. SHORT TITLE. 
This Act may be cited as the ‘‘Electricity Trans-
mission Scorecard Act’’. 
SEC. 2. FINDINGS. 
Congress finds the following: 
VerDate Sep 11 2014 
18:36 Nov 28, 2025
Jkt 069200
PO 00000
Frm 00001
Fmt 6652
Sfmt 6201
E:\BILLS\H6176.IH
H6176
kjohnson on DSK7ZCZBW3PROD with $$_JOB
(1) Electricity transmission facilities and serv-
ices provided by covered transmission owners affect 
interstate commerce and are essential to the Na-
tion’s economic well-being and national security. 
(2) Transparent, standardized performance 
data on transmission systems promotes cost-effective 
investment, prevents unduly discriminatory prac-
tices, and protects ratepayers. 
(3) Existing reporting requirements are frag-
mented, inconsistent, and do not allow for meaning-
ful 
comparison 
among 
transmission 
providers, 
RTOs, and ISOs. 
(4) To ensure that all transmitting utilities are 
subject to uniform, non-discriminatory access obliga-
tions, to safeguard the public interest in the reli-
ability, affordability, and efficiency of the interstate 
transmission system, and to ensure the development 
of just and reasonable rates, a common performance 
reporting framework is necessary. 
(5) Systemic transparency across all utilities 
engaged in transmitting electricity enables rate-
payers, investors, generators, regulators, researchers, 
and other stakeholders and market participants to 
clearly compare transmission rates, outcomes, and 
practices across regions and governance structures. 
VerDate Sep 11 2014 
18:36 Nov 28, 2025
Jkt 069200
PO 00000
Frm 00002
Fmt 6652
Sfmt 6201
E:\BILLS\H6176.IH
H6176
kjohnson on DSK7ZCZBW3PROD with $$_JOB
(6) Market and policy innovation in the elec-
tricity sector is enhanced by making grid perform-
ance data publicly available, thus empowering inde-
pendent research, enabling competition, and reduc-
ing information asymmetries between utilities and 
external actors. 
(7) The quality of economic, reliability, and en-
vironmental outcomes delivered to customers can im-
prove as a result of performance-based account-
ability. 
(8) It is in the best interest of the Nation to 
require standardized data submissions and scorecard 
reporting from all utilities engaged in transmitting 
electricity, including those not subject to section 205 
or 206 of the Federal Power Act, to evaluate wheth-
er service comparability and nondiscrimination obli-
gations are being met and to ensure that ratepayers 
are not burdened by inefficiencies, lack of invest-
ment, or the absence of cost-effective solutions that 
would increase capacity, reduce congestion, facilitate 
interconnection, or otherwise reduce unnecessary 
costs and reliability concerns for ratepayers. 
SEC. 
3. 
PERFORMANCE 
SCORECARD 
ELEMENTS 
AND 
VERIFICATION. 
(a) REPORTING REQUIREMENTS.— 
VerDate Sep 11 2014 
18:36 Nov 28, 2025
Jkt 069200
PO 00000
Frm 00003
Fmt 6652
Sfmt 6201
E:\BILLS\H6176.IH
H6176
kjohnson on DSK7ZCZBW3PROD with $$_JOB
(1) TRANSMISSION
INVESTMENT, 
ACCOUNT-
ABILITY, AND PERFORMANCE SCORECARDS.— 
(A) IN GENERAL.—The Commission shall 
require each covered transmission owner to bi-
annually develop, publish, and submit to the 
Secretary a report, to be known as a Trans-
mission Investment, Accountability, and Per-
formance Scorecard (or a TIAPS report), that 
includes metrics evaluating the following: 
(i) 
Ratepayer 
affordability, 
which 
shall assess the cost of transmission serv-
ices per unit of energy transmitted or 
other metrics that can be used to assess 
affordability of energy provided to rate-
payers. 
(ii) Financing costs, which shall as-
sess the financing structure and cost of 
capital for a covered transmission owner, 
and may include consideration of capital 
structure and leverage ratios, reliance on 
formula rates or other automatic adjust-
ment mechanisms, allowed and earned re-
turns on equity, the cost of debt and pre-
ferred stock, the presence and magnitude 
VerDate Sep 11 2014 
18:36 Nov 28, 2025
Jkt 069200
PO 00000
Frm 00004
Fmt 6652
Sfmt 6201
E:\BILLS\H6176.IH
H6176
kjohnson on DSK7ZCZBW3PROD with $$_JOB
of incentive rate adders, and other related 
metrics. 
(iii) Investment prudency and cost re-
covery, which shall assess the prudency of 
capital investments and the transparency 
and structure of associated cost recovery 
mechanisms, and may include the fre-
quency and magnitude of cost disallow-
ances in rate proceedings, the types of fa-
cilities or investments associated with dis-
allowed costs, the degree of cost recovery 
from ratepayers relative to shareholder 
contributions, and the transparency and 
accountability of cost allocation frame-
works. 
(iv) Investment effectiveness, which 
shall assess the value delivered by covered 
transmission owner investments relative to 
their costs, including how effectively the 
covered transmission owner considered and 
deployed the most economically efficient 
solutions to reduce cost burden on rate-
payers and the accuracy of project cost es-
timates, and may include metrics related to 
benefit-cost analyses, investments in ad-
VerDate Sep 11 2014 
18:36 Nov 28, 2025
Jkt 069200
PO 00000
Frm 00005
Fmt 6652
Sfmt 6201
E:\BILLS\H6176.IH
H6176
kjohnson on DSK7ZCZBW3PROD with $$_JOB
vanced technology deployment, non-wires 
alternatives, reconductoring, grid-enhanc-
ing technologies, or other operational up-
grades that avoid higher cost capital in-
vestment, estimated and actual cost for 
new or updated assets, and other indica-
tors of prudent capital deployment. 
(v) Capital expenditure bias, which 
shall assess the covered transmission own-
er’s balance of spending on capital invest-
ment versus operational and maintenance 
activities. 
(vi) System reliability and availability, 
which shall assess the operational perform-
ance of the transmission facilities of the 
covered transmission owner over the re-
porting period, including information re-
lated to outages, equipment availability, 
and resilience to system disturbances, and 
may be expressed using existing trans-
mission-specific reliability indicators, as de-
scribed by the North American Electric 
Reliability Corporation or other entity es-
tablished to oversee and administer reli-
ability standards and procedures for the 
VerDate Sep 11 2014 
18:36 Nov 28, 2025
Jkt 069200
PO 00000
Frm 00006
Fmt 6652
Sfmt 6201
E:\BILLS\H6176.IH
H6176
kjohnson on DSK7ZCZBW3PROD with $$_JOB
bulk-power system, metrics regarding the 
economic costs of outages or lost reli-
ability, or other related metrics. 
(vii) Physical system performance, 
which shall assess how effectively the 
transmission facilities owned, operated, or 
controlled by the covered transmission 
owner are used to deliver electricity, in-
cluding both physical and economic per-
formance, and may include technical and 
non-technical losses, utilization relative to 
rated capacity and design constraints, age 
of system components, and other indicators 
of transmission system utilization, per-
formance, and efficiency. 
(viii)(I) Interconnection and access 
fairness, which shall assess the extent to 
which the interconnection process for inter-
regional interconnections and new facilities 
(including generators, energy storage, load, 
and merchant transmission projects) is 
conducted in a timely and impartial man-
ner consistent with Commission regula-
tions, including comparisons between affili-
ated entities and unaffiliated entities, and 
VerDate Sep 11 2014 
18:36 Nov 28, 2025
Jkt 069200
PO 00000
Frm 00007
Fmt 6652
Sfmt 6201
E:\BILLS\H6176.IH
H6176
kjohnson on DSK7ZCZBW3PROD with $$_JOB
may be expressed as the difference in the 
number of days from initial interconnection 
request to execution of an Interconnection 
Agreement, or through related measures of 
procedural equity. 
(II) For purposes of this clause: 
(aa) The term ‘‘affiliated entity’’ 
means any entity that has a direct or 
indirect relationship with a covered 
transmission owner or its parent enti-
ty that could reasonably influence 
interconnection treatment, including 
an entity that— 
(AA) shares common owner-
ship or controlling interest with 
the covered transmission owner 
or its parent entity; 
(BB) is a direct or indirect 
subsidiary of the covered trans-
mission owner or its parent enti-
ty; 
(CC) is engaged in a joint 
venture, contractual partnership, 
or strategic alliance with the cov-
ered transmission owner or its 
VerDate Sep 11 2014 
18:36 Nov 28, 2025
Jkt 069200
PO 00000
Frm 00008
Fmt 6652
Sfmt 6201
E:\BILLS\H6176.IH
H6176
kjohnson on DSK7ZCZBW3PROD with $$_JOB
parent entity, where such part-
nership includes shared financial 
interest, 
revenue 
sharing, 
or 
asset co-development; or 
(DD) is otherwise deter-
mined by the Commission to have 
a financial, governance, or oper-
ational relationship that may rea-
sonably be expected to influence 
interconnection prioritization. 
(bb) The term ‘‘unaffiliated enti-
ty’’ means any entity that— 
(AA) has logged an inter-
connection request with the cov-
ered transmission owner; and 
(BB) is not an affiliated en-
tity. 
(ix) Non-operational cost recovery, 
which shall assess the amount of covered 
transmission owner spending on lobbying, 
advertising, penalties, and advocacy activi-
ties recovered through customer rates, and 
may be expressed as expenditures on each 
such activity, a total sum of expenditures 
on such activities, or related metrics. 
VerDate Sep 11 2014 
18:36 Nov 28, 2025
Jkt 069200
PO 00000
Frm 00009
Fmt 6652
Sfmt 6201
E:\BILLS\H6176.IH
H6176
kjohnson on DSK7ZCZBW3PROD with $$_JOB
(x) Interregional and regional plan-
ning integration, which shall assess the ex-
tent to which the covered transmission 
owner participates in coordinated regional 
and interregional transmission planning 
processes and infrastructure development, 
and may be expressed as the number and 
capacity of interregional transmission ties, 
the share of projects subject to regional or 
interregional planning review, or related 
metrics. 
(xi) Any additional matters that— 
(I) may be evaluated using out-
come-based performance metrics iden-
tified by the Commission, giving pref-
erence to quantitative metrics over 
qualitative metrics; and 
(II) the Commission determines 
are 
necessary 
to 
improve 
trans-
parency, affordability, reliability, eq-
uity, or environmental performance of 
the facilities owned, operated, or con-
trolled by the covered transmission 
owner. 
(B) EXEMPTIONS.— 
VerDate Sep 11 2014 
18:36 Nov 28, 2025
Jkt 069200
PO 00000
Frm 00010
Fmt 6652
Sfmt 6201
E:\BILLS\H6176.IH
H6176
kjohnson on DSK7ZCZBW3PROD with $$_JOB
(i) CATEGORIES.—The Commission 
may, by rule, exempt all covered trans-
mission owners in a category of covered 
transmission owners from the requirement 
to include a metric described in subpara-
graph (A) if the Commission determines 
that the metric is demonstrably inappli-
cable to all covered transmission owners in 
the category. 
(ii) SCOPE.—The Commission shall 
ensure that the scope of any metric from 
which a category of covered transmission 
owners is exempted under this subpara-
graph is as narrow as possible in order to 
preserve consistency and comparability 
among scorecards. 
(C) COORDINATION.—In preparing and de-
veloping a scorecard pursuant to this para-
graph, a covered transmission owner shall co-
ordinate, as necessary to obtain or estimate 
data required to be included in a scorecard 
under this section, with any relevant entity, in-
cluding— 
(i) regional grid operators, including 
Independent System Operators, Regional 
VerDate Sep 11 2014 
18:36 Nov 28, 2025
Jkt 069200
PO 00000
Frm 00011
Fmt 6652
Sfmt 6201
E:\BILLS\H6176.IH
H6176
kjohnson on DSK7ZCZBW3PROD with $$_JOB
Transmission Organizations, transmission 
planning entities, and balancing authori-
ties; 
(ii) interconnected electric utilities, in-
cluding load serving entities and other 
transmission providers; 
(iii) owners of generation facilities, in-
cluding utility-scale and merchant genera-
tors seeking interconnection or operating 
within the service territory of the covered 
transmission owner; and 
(iv) regulatory and oversight entities, 
including State public utility commissions, 
and applicable Federal or State energy, re-
liability, or environmental agencies. 
(2) REGIONAL INVESTMENT, ACCOUNTABILITY, 
AND PERFORMANCE SCORECARDS.—The Commission 
shall require each Independent System Operator, 
Regional Transmission Organization, and trans-
mission planning entity to annually develop, publish, 
and submit to the Secretary a report, to be known 
as a Regional Investment, Accountability, and Per-
formance Scorecard (or a RIAPS report), that in-
cludes the following: 
VerDate Sep 11 2014 
18:36 Nov 28, 2025
Jkt 069200
PO 00000
Frm 00012
Fmt 6652
Sfmt 6201
E:\BILLS\H6176.IH
H6176
kjohnson on DSK7ZCZBW3PROD with $$_JOB
(A) Aggregation of the metrics reported 
for the year in the scorecards submitted under 
paragraph (1) by the covered transmission own-
ers within the jurisdiction of the applicable 
ISO, RTO, or transmission planning entity, 
which shall consist of a summary of such 
metrics that— 
(i) reflects weighted or capacity-ad-
justed averages of covered transmission 
owner-reported metrics, as appropriate; 
(ii) highlights significant intra-re-
gional variation or performance outliers; 
and 
(iii) does not obscure material dif-
ferences among transmission owners or re-
gions. 
(B) Regional-specific metrics, which shall 
consist of reporting on metrics specific to oper-
ational responsibilities of the ISO, RTO, or 
transmission planning entity, including the fol-
lowing: 
(i) Market efficiency, which shall as-
sess the extent to which the ISO, RTO, or 
transmission planning entity is successful 
in operating efficient wholesale electricity 
VerDate Sep 11 2014 
18:36 Nov 28, 2025
Jkt 069200
PO 00000
Frm 00013
Fmt 6652
Sfmt 6201
E:\BILLS\H6176.IH
H6176
kjohnson on DSK7ZCZBW3PROD with $$_JOB
markets, minimizing system congestion, 
and maximizing the use of existing grid in-
frastructure to deliver cost-effective out-
comes for consumers while maintaining re-
quired standards of reliability, and may be 
expressed as average energy and ancillary 
service costs (system-wide and by major 
zone), system and zonal capacity costs 
where applicable, congestion costs, out-of- 
market payments, frequency of redispatch, 
implementation 
of 
congestion-relieving 
technologies, or related metrics. 
(ii) Regional interconnection perform-
ance, which shall assess the effectiveness 
and efficiency of interconnection processes, 
and may include metrics that measure the 
duration of queue processing, the rate of 
project withdrawals, and the share of 
projects that successfully reach commercial 
operation, or related metrics. 
(iii) Regional and interregional devel-
opment, which shall assess the extent and 
effectiveness of regional and interregional 
transmission planning and buildout, and 
may be expressed in relation to the number 
VerDate Sep 11 2014 
18:36 Nov 28, 2025
Jkt 069200
PO 00000
Frm 00014
Fmt 6652
Sfmt 6201
E:\BILLS\H6176.IH
H6176
kjohnson on DSK7ZCZBW3PROD with $$_JOB
and total capacity of transmission lines de-
veloped through regional and interregional 
planning processes, the proportion of new 
transmission projects selected through re-
gional planning processes versus those ad-
vanced outside of such processes (including 
local or supplemental projects), the number 
of projects selected through competitive 
processes, the use and outcomes of benefit- 
cost analysis in project selection and devel-
opment, the frequency of stakeholder en-
gagement, the ratio of total investment in 
interregional and regional transmission to 
investment in local transmission, or other 
related metrics. 
(iv) Seams management and resolu-
tion, which shall assess the extent to which 
the ISO, RTO, or transmission planning 
entity identifies and addresses seams, and 
may include the number of seams-related 
studies initiated or completed, the quantity 
and capacity of interties enabling cross-re-
gional power flows, and the frequency or 
magnitude of congestion and price diver-
gence across seams. 
VerDate Sep 11 2014 
18:36 Nov 28, 2025
Jkt 069200
PO 00000
Frm 00015
Fmt 6652
Sfmt 6201
E:\BILLS\H6176.IH
H6176
kjohnson on DSK7ZCZBW3PROD with $$_JOB
(v) Greenhouse gas emissions inten-
sity, which shall assess, through the use of 
methodologies specified by the Commission 
based on input from the Administrator of 
the Environmental Protection Agency, the 
emissions profile of electricity delivered 
within the service territory of the ISO, 
RTO, or transmission planning entity in 
the reporting year, and may be expressed 
as the emissions intensity of delivered elec-
tricity in carbon dioxide equivalents per 
megawatt-hour, or related metrics. 
(vi) Any additional outcome-based 
performance metrics the Commission de-
termines necessary to improve trans-
parency, affordability, reliability, equity, or 
environmental performance of the trans-
mission system overseen by the RTO, ISO, 
or transmission planning entity. 
(3) DATA DISCLOSURE.—Each reporting entity 
shall publish and submit to the Secretary, with each 
scorecard published under this subsection, all non- 
confidential underlying data supporting the metrics 
included in the scorecard, in a machine-readable, 
open-data format. 
VerDate Sep 11 2014 
18:36 Nov 28, 2025
Jkt 069200
PO 00000
Frm 00016
Fmt 6652
Sfmt 6201
E:\BILLS\H6176.IH
H6176
kjohnson on DSK7ZCZBW3PROD with $$_JOB
(4) INITIAL REPORTING.—Each reporting entity 
shall publish and submit to the Secretary its first 
scorecard not later than 6 months after the date on 
which the Commission issues a final rule under sub-
section (e)(1). 
(b) METRIC
AND
METHODOLOGY
STANDARDIZA-
TION.— 
(1) IN GENERAL.—The Commission, with input 
from the Secretary, the Administrator, the National 
Laboratories, and other stakeholders, where appro-
priate, shall standardize the metrics required to be 
included in a scorecard under subsection (a) and the 
methodologies for calculating such metrics, including 
by ensuring that the definitions, data sources, and 
calculation methodologies for each metric are uni-
form among all reporting entities, except as provided 
in paragraph (2). 
(2) EXCEPTION FOR NECESSARY REGIONAL OR 
STRUCTURAL DIFFERENCES.—In carrying out para-
graph (1), the Commission may allow for a dif-
ference among reporting entities in metrics or meth-
odologies only upon issuance of a written determina-
tion that the difference is demonstrably necessary on 
a regional or structural basis. 
VerDate Sep 11 2014 
18:36 Nov 28, 2025
Jkt 069200
PO 00000
Frm 00017
Fmt 6652
Sfmt 6201
E:\BILLS\H6176.IH
H6176
kjohnson on DSK7ZCZBW3PROD with $$_JOB
(3) BENEFIT-COST ANALYSIS.—In carrying out 
paragraph (1), the Commission shall establish uni-
form requirements for any benefit-cost analyses to 
be included in a scorecard under subsection (a), in-
cluding minimum parameters, data sources, and as-
sumptions to ensure comparability among reporting 
entities and to prevent selective or undisclosed mod-
eling assumptions that materially affect reported re-
sults. 
(c) VERIFICATION REQUIREMENTS.— 
(1) IN GENERAL.—The Commission shall estab-
lish a process by which scorecards required to be de-
veloped under subsection (a) are verified by inde-
pendent evaluators to ensure accuracy, consistency, 
and credibility prior to publication under such sub-
section. The Commission shall include in such proc-
ess— 
(A) requirements for the approval by the 
Commission of independent evaluators, includ-
ing requirements that an independent eval-
uator— 
(i) possess demonstrated expertise in 
electric transmission planning, data valida-
tion, engineering analysis, regulatory ac-
counting, or grid performance evaluation, 
VerDate Sep 11 2014 
18:36 Nov 28, 2025
Jkt 069200
PO 00000
Frm 00018
Fmt 6652
Sfmt 6201
E:\BILLS\H6176.IH
H6176
kjohnson on DSK7ZCZBW3PROD with $$_JOB
including experience with relevant mod-
eling tools and with data systems of the 
Commission or the Department of Energy; 
(ii) possess or otherwise have access 
to technical and analytical expertise appro-
priate to the metrics being verified, includ-
ing in engineering, economics, data ana-
lytics, or regulatory accounting; and 
(iii) be independent from the entity 
being verified and have no financial, con-
tractual, or governance conflicts of inter-
est, including having no affiliation or com-
mon ownership with any entity responsible 
for managing or overseeing the pension or 
benefit funds of a reporting entity; 
(B) procedures for auditing the assump-
tions and methodologies used in applying per-
formance metrics, including to detect selective 
reporting and ensure alignment with Commis-
sion-defined protocols; 
(C) requirements to ensure that any single 
independent evaluator, or their parent company 
or subsidiary— 
(i) may not evaluate a reporting entity 
that is a covered transmission owner more 
VerDate Sep 11 2014 
18:36 Nov 28, 2025
Jkt 069200
PO 00000
Frm 00019
Fmt 6652
Sfmt 6201
E:\BILLS\H6176.IH
H6176
kjohnson on DSK7ZCZBW3PROD with $$_JOB
than 5 reporting periods in a row, or more 
than 15 times in any 10-year period; and 
(ii) may not evaluate a reporting enti-
ty that is an ISO, RTO, or transmission 
planning entity more than 3 reporting peri-
ods in a row, or more than 7 times in any 
10-year period; 
(D) requirements under which an inde-
pendent evaluator approved by the Commission 
may verify the information in the scorecard of 
the reporting entity, by reviewing supporting 
documentation, conducting project inspections, 
and applying standardized evaluation, measure-
ment, and verification protocols for the metrics 
included in the scorecard; 
(E) requirements for public disclosure of 
the results of such verification, including any 
adjustments to reported values, methodologies 
used in the verification process, and justifica-
tions for material discrepancies; and 
(F) a process for reviewing and refining 
verification protocols at regular intervals, not 
less frequently than once every 3 years, in con-
sultation with any relevant stakeholder advisory 
group convened under section 5, to incorporate 
VerDate Sep 11 2014 
18:36 Nov 28, 2025
Jkt 069200
PO 00000
Frm 00020
Fmt 6652
Sfmt 6201
E:\BILLS\H6176.IH
H6176
kjohnson on DSK7ZCZBW3PROD with $$_JOB
advances in data analytics, energy system mod-
eling, and grid performance assessment. 
(2) ROLE
OF
NATIONAL
LABORATORIES.—In 
carrying out this subsection, the Commission shall— 
(A) collaborate with National Laboratories 
that have the necessary expertise, in coordina-
tion with the Secretary, to design and publish 
standardized verification protocols, including 
templates, analytical tools, and calibration 
datasets; 
(B) utilize the technical expertise of Na-
tional Laboratories to assist in the training, 
evaluation, or approval of independent eval-
uators; 
(C) engage National Laboratories in con-
ducting selective audits or quality assurance re-
views of verified scorecards during initial imple-
mentation of the scorecard reporting and 
verification process and implementation of any 
subsequent updates to such scorecards; and 
(D) consult National Laboratories during 
periodic updates to the verification process, in 
coordination with any relevant stakeholder advi-
sory group convened under section 5. 
(d) INDEPENDENT AUDITS.— 
VerDate Sep 11 2014 
18:36 Nov 28, 2025
Jkt 069200
PO 00000
Frm 00021
Fmt 6652
Sfmt 6201
E:\BILLS\H6176.IH
H6176
kjohnson on DSK7ZCZBW3PROD with $$_JOB