ANNUAL REPORT 2021
2021 FINANCIAL HIGHLIGHTS
KEY ACCOMPLISHMENTS
• Paid annualized dividend of $1.56 per common share consistent with dividend policy
• Announced a transformational equity raise of $3.4 billion to enhance our credit profile, fund strategic investments and
fully address equity needs
• Raised 2021-2025 investment plan to $17 billion, supporting continued work to strengthen and enhance the reliability
of our transmission and distribution system and drive the transition to a reduced carbon future
• Provided 2021 total shareholder return of 41.8%, second among our peers in the 39-member EEI Index
FINANCIALS AT A GLANCE
TOTAL REVENUES (in millions)
BASIC EARNINGS PER SHARE (GAAP)
OPERATING EARNINGS PER SHARE (non-GAAP*)
DIVIDENDS PAID PER COMMON SHARE
2019
$11,035
$1.70
$2.58
$1.52
2020
$10,790
$1.99
$2.39
$1.56
2021
$11,132
$2.35
$2.60
$1.56
ANNUAL INVESTMENTS
(in $ millions)
TRANSMISSION RATE BASE
(in $ millions)
DISTRIBUTION RATE BASE
(in $ millions)
2,992
2,986
2,874
3,000
8,100
9,000
8,000
7,585
16,200
15,510
2,500
6,945
7,000
14,820
2,000
1,500
1,000
500
0
6,000
5,000
4,000
3,000
2,000
1,000
0
2019
2020
2021
2019
2020
2021
2019
2020
2021
* See non-GAAP Financial Measures information on the inside back cover of this report.
On the cover: This is a time of renewal and growth at FirstEnergy as we cultivate a sustainable company that is centered on our Core Values.
17,000
16,000
15,000
14,000
13,000
12,000
11,000
10,000
0
A MESSAGE TO
OUR SHAREHOLDERS
Throughout 2021, we engaged in reflection and redirection,
which resulted in substantial progress to transform FirstEnergy
and deliver long-term value to our stakeholders. We’ve made
many changes to resolve legacy issues, strengthen our financial
position and capitalize on sustainable strategic investments
designed to serve our customers’ evolving energy needs. I’m
proud of our progress in these areas, and together with our
strong business model and operational momentum, I’ve never
been more excited about our future.
Inspired by open and ongoing dialogue with diverse stakeholders,
we’re not only conducting our business better, but also doing
better for the world around us by improving our performance on
a range of environmental, social and governance (ESG) matters.
Keeping integrity at the center of our business practices and daily
behaviors, we’re moving forward with clarity, confidence and a
renewed sense of purpose as we reshape FirstEnergy into a more
innovative, diverse and sustainable company.
MOVING FE FORWARD
By optimizing operations, accelerating our digital transformation
and enhancing our business policies and practices, FE Forward
is modernizing and transforming our company while opening
additional opportunities for long-term growth. In the first full
year, FE Forward initiatives achieved $300 million in net capital
expenditure efficiencies and working capital improvements,
exceeding our initial projections. Through 2025, we anticipate
cumulative free cash flow improvements of more than $1.7 billion.
These savings provide opportunities for reinvestment into strategic
opportunities to better serve our customers, act on our ESG
initiatives and support our Climate Strategy as we transition to a
smarter and cleaner electric grid.
As part of FE Forward, employees were called upon to develop
a more strategic approach to operating expenditures. As a
result, our 10 utility companies consolidated their operations to
a five-state model that increases efficiency and standardization
across our service area. The new organization supports our
customer-focused business strategy, maintains a sharp focus
on our operations and optimizes how we manage our assets and
resources. This new structure will enable us to deliver a superior
customer experience as we work to become a more efficient and
effective industry leader.
Steven E. Strah
President and
Chief Executive Officer
While we are evolving, our priority remains constant – to provide
our customers with safe, reliable, sustainable and affordable
energy. Using a data-driven approach, we are developing ways to
offer a best-in-class experience that enables us to meet customers
wherever they are on their energy journey – from exploring
renewable energy possibilities and adopting energy efficiency
practices, to reporting outages and navigating bill assistance
programs. We’re improving customer interactions with our contact
centers and digital channels, expanding public safety outreach
and continuing to support our low-income customers’ needs
throughout the clean energy transition.
BOLSTERING OUR FINANCIAL POSITION
AND SUPPORTING SUSTAINABLE
INVESTMENTS
In November, we announced strategic financings with two premier
global infrastructure funds, Blackstone Infrastructure Partners
and Brookfield Super-Core Infrastructure Partners, that will raise
a combined $3.4 billion in equity proceeds. Blackstone purchased
$1 billion in FirstEnergy common stock, while Brookfield agreed to
purchase a 19.9% stake in FET LLC, which owns our ATSI, MAIT
and TrAILCo transmission entities.
Both Blackstone and Brookfield are experienced and capable
infrastructure investors who fully support the execution and
acceleration of our current business strategy and transformation.
Additionally, these financings demonstrate substantial confidence
in our business model, our talented teams and our vision for
long-term growth. In fact, we achieved a historic premium
valuation for the FET transaction compared to other transactions
in the utility sector.
These transactions recapitalize our balance sheet and fully address
our equity needs, better positioning us to strengthen our credit
profile and achieve core rating agency metrics. This enhanced
financial strength also better situates FirstEnergy to fulfill our
long-term strategy by capitalizing on investment opportunities
including advanced smart grid technologies and clean energy
programs for our customers and communities.
A n n u a l R e p o r t I 1
IN 2021,
$676 MILLION
OF OUR TOTAL TRANSMISSION INVESTMENT WAS
FOCUSED ON RELIABILITY IMPROVEMENTS.
FOCUSING ON THE FUTURE OF ENERGY
In November, we also announced a $2.2 billion increase in our five-year investment
plan and introduced a long-term earnings growth rate of 6% to 8%. Our plan, which
now totals $17 billion from 2021 to 2025, supports our continued work to strengthen
and enhance the reliability of our transmission and distribution system and drive the
transition to a decarbonized economy.
More than $10 billion of the plan is focused on sustainable investments to enable
our customers to thrive in a reduced carbon future. These investments are expected
to support a more resilient electric grid while placing an emphasis on emerging
technologies, grid modernization, electric vehicle (EV) infrastructure and solutions to
help customers manage their energy use.
With over 700 projects undertaken last year alone, our long-term, multibillion-dollar
Energizing the Future initiative continues to modernize FirstEnergy’s transmission
assets, enhance operational capabilities and expand load capacity to make the grid
more reliable and resilient. These significant transmission investments also support
our Climate Strategy by hardening the grid against increasingly violent storms and
providing the flexibility needed to incorporate more renewable energy resources.
Across our service area, we’re replacing or rebuilding existing lines and substations,
and adding new facilities to meet anticipated load growth and other operational
challenges.
For example, we’re reconfiguring substations across our service area to increase
capacity, reduce the probability of equipment failure and respond quickly to supply
disruptions. In south central Pennsylvania, we upgraded a substation to increase
the capacity of the transformer that connects the West Penn Power and Penelec
systems, providing a more reliable substation configuration. Another upgrade in Erie,
Pennsylvania, helps prevent potential outages on the 115-kilovolt (kV) system through
a substation configuration that is more reliable and leaves room for future expansion.
Such infrastructure investments are driving measurable performance improvements
for our customers, including a 38% reduction through 2021 in transmission-related
distribution outages on our ATSI system, which serves our three utility companies
in Ohio and our Penn Power utility in western Pennsylvania.
Our transmission investments are also supporting the energy demands of the
rapidly expanding EV industry in Ohio’s “Voltage Valley.” We’re building a new
138-kV circuit that extends approximately 3.5 miles to connect electric substations
in the area, strengthening the regional transmission system to benefit more than
15,000 customers in Lordstown and nearby communities. When completed, the
line will ensure supply continuity to customers during maintenance and unplanned
system outages.
Beyond aligning with our goal to support widespread electrification efforts, the
Voltage Valley transmission upgrade enables much needed job growth in the area.
We’re proud to support work that advances regional business development while
strengthening our system to meet the growing demand for safe and reliable power
for many years to come. Recognized by Site Selection magazine as one of the nation’s
leading utilities in promoting economic development from 2018-2020, FirstEnergy
continues to advance economic development across our service area – helping to
attract 21,820 new jobs and $5.4 billion in third-party corporate facility investment
in 2021.
2 I A n n u a l R e p o r t
On the distribution side of our business, we’re envisioning a
reduced carbon future in which the distribution system supports
economy-wide electrification, increased distributed energy
resources, smart cities and more. We are strengthening our
system with smart technologies, machine learning and advanced
automation to prepare the grid for that future.
In Ohio, we are completing the first phase of our three-year
Grid Modernization Plan, which is designed to modernize the
distribution system with automated equipment, real-time voltage
controls and smart technologies. Our Ohio Smart Meter team
made great progress toward our goal of deploying 700,000 smart
meters in Ohio, despite challenges, schedule delays and supply
chain issues related to the COVID-19 pandemic. By improving
accuracy and automating communication, smart meters help us
reduce the number of estimated bills and improve our ability to
respond to power outages faster and more efficiently. Customers
will also have access to more detailed energy information through
our online Home Energy Analyzer tool that can assist them in
better understanding their electricity use.
In Maryland, Potomac Edison completed two new distribution
automation projects as part of a broader initiative approved by the
Maryland Public Service Commission to enhance service reliability
and reduce outages for customers. These projects enable us to
automatically switch customers to adjacent power lines when
damage occurs on a line, resulting in faster power restoration for
more than 4,000 customers in Garrett and Carroll counties.
Additionally, Potomac Edison’s EV Driven program supports
Maryland’s electrification efforts. Our plans call for installing
59 EV charging stations, including 20 fast-charging stations,
which provide an 80% charge for most vehicles in less than an
hour. Potomac Edison also offers rebates for both residential
and multifamily charger installations and incentives for EV
charging during off-peak hours.
These and other distribution projects across our five-state
service area are designed to upgrade our system and enhance
our customers’ experience by improving service reliability while
enabling us to meet the growing demand for cleaner energy
options in a decarbonized economy.
STRENGTHENING ETHICS AND
CORPORATE GOVERNANCE
Our new Code of Conduct, The Power of Integrity, demonstrates
our commitment to building a best-in-class ethics, integrity and
accountability culture at every level of the organization. Leaders
are focused on fostering a positive and inclusive work environment
where all employees feel engaged and inspired to speak up and
empowered to always do the right thing. To further bolster this
culture change, we implemented a new ethics and compliance key
performance modifier in our annual short-term incentive program
for employees.
We’re also developing a new approach to public policy
engagement that aligns more closely with our strategic goals
and Core Values and that includes more robust oversight and
disclosure of our advocacy efforts. In recognition of changes
we’ve already put in place, we were designated as a 2021
“trendsetter” for transparency in our political disclosures
by the CPA-Zicklin Index of Corporate Political Disclosure
and Accountability. Our new Corporate Engagement Report
assesses alignment between the 501(c)(4) and 501(c)(6) trade
organizations we support and our climate position and strategy –
including our pledge to achieve carbon neutrality by 2050 and
our support for the intent of the Paris Agreement.
FE FORWARD IN ACTION
Data scientists from FirstEnergy’s
Innovation and Digital Enablement team
have been working with Met-Ed’s Forestry
employees to create and test a data-driven
predictive model to pinpoint power lines
that are most susceptible to tree-related
outages. Their goal is to improve reliability
by proactively directing vegetation
maintenance resources to areas that will
provide the greatest value. We’re excited
to consider how we can use this model
to minimize storm impacts over time and
improve reliability for our customers.
In addition, while we continue to electrify
our fleet, we’ve also taken measures to
limit the idling of gas- and diesel-powered
vehicles to improve fuel efficiency and
reduce maintenance costs. These actions
also aim to further reduce tailpipe
emissions and limit noise pollution in
the communities we serve.
A n n u a l R e p o r t I 3
The actions taken to enhance our Board,
strengthen our leadership team, build a
best-in-class compliance program and
significantly modify our approach to political
engagement enabled FirstEnergy to reach
an agreement with the U.S. Attorney’s Office
for the Southern District of Ohio to resolve
the Department of Justice investigation.
Announced in July, the deferred prosecution
agreement, which included a $230 million
payment, noted our substantial cooperation
from the onset of the investigation and
recognized the significant remedial actions
we’ve taken to better reflect the culture of
integrity and trust we strive to uphold at
FirstEnergy.
We reached another significant milestone
in November, when our Ohio utilities
negotiated an agreement to resolve multiple
proceedings under consideration by the
Public Utilities Commission of Ohio (PUCO).
The Ohio companies worked openly and
collaboratively with 11 parties to reach a
unanimous resolution that will provide
$306 million in benefits to Ohio utility
customers. While other proceedings related
to Ohio House Bill 6 remain outstanding,
we have made meaningful progress toward
resolving outstanding litigation in order to
provide certainty to stakeholders and focus
our attention on the future.
Our leadership team, energized by dynamic
collaborations among established leaders
and an influx of new leaders appointed
at both the board and executive levels, is
committed to creating an environment
where our actions closely align with
our Mission and Core Values.
4 I A n n u a l R e p o r t
PROMOTING ENVIRONMENTAL STEWARDSHIP
Reducing greenhouse gas (GHG) emissions within our direct control by 30% by
2030 (from 2019 baseline) and achieving carbon neutrality by 2050 are key aspects
of our Climate Strategy and larger commitment to environmental stewardship.
As part of FirstEnergy’s efforts to reduce GHG emissions, the first hybrid electric
bucket trucks in our vehicle fleet were deployed in December 2021 in our
JCP&L service area. This rollout continues as we implement our plan to electrify
30% of our approximately 3,400 light duty and aerial fleet vehicles by 2030,
reaching 100% electrification by 2050. This initiative has the potential to eliminate
approximately 10,000 metric tons of GHG emissions annually – equivalent to
removing nearly 2,200 cars from the road each year – while
saving nearly 4 million gallons of fuel from 2021 through 2030.
As described in our Climate Strategy, we expect to thoughtfully transition away from
our regulated coal generation fleet in West Virginia no later than 2050, and we have
announced our plans to begin a broad stakeholder dialogue regarding our planned
operational end dates of 2035 and 2040 for the Fort Martin and Harrison power
plants, respectively. In the meantime, Mon Power and Potomac Edison have filed with
the Public Service Commission of West Virginia for approval to undertake a multiyear
environmental compliance program at our two plants. The approximately $142 million
investment would enable new wastewater treatment projects necessary to meet the
U.S. Environmental Protection Agency’s effluent limitation guideline requirements for
plants operating beyond 2028.
We also continue to evaluate opportunities to support renewable energy across our
service territory. Mon Power and Potomac Edison have filed with the Commission
for approval to build five utility-scale solar energy projects throughout the
companies’ West Virginia service territory. Together, the facilities would generate
50 megawatts of renewable energy, helping to advance more sustainable energy
options for customers and make West Virginia more attractive for business
development. In addition, JCP&L has submitted a proposal to connect clean energy
generated by New Jersey’s offshore wind farms to the power grid. The proposal,
which supports significant investments in clean energy driven by the New Jersey
Energy Master Plan, is designed to connect future offshore wind farms with the grid
through existing transmission infrastructure and rights-of-way.
Through our Integrated Vegetation Management program, we help preserve
biodiversity, minimize the environmental impact of our operations and promote
excellence in sustainable utility vegetation management. Since the program began
in 2020, we’ve planted nearly 100 acres of newly created pollinator habitat, making
significant progress toward our goal to create 225 acres of biodiverse habitats on
utility rights-of-way and company properties across our service area. As a result of
our industry-leading efforts, FirstEnergy is now a fully accredited Right-of-Way (ROW)
Utility Steward through the ROW Stewardship Council, which
independently evaluates standards of excellence for vegetation
management and utility practices.
Aligned with our stewardship focus and commitment to developing
increasingly responsible, sustainable operations, we continuously
evaluate opportunities to expand recycling and waste reduction
efforts across the company. For example, following a successful
pilot with Ohio Edison, our Utility Pole Recycling Program is now
activated across our company. The program diverted 600 tons
of wood poles from landfills in 2021. In addition to expanding
recycling of company equipment, we began piloting a program in
2021 to properly recycle employees’ personal electronic waste,
which often contains chemicals harmful to the environment. At just
one Employee Electronic Waste Collection event at a company facility
in West Virginia, we collected approximately 850 pounds of electronic
waste, diverting that material from possible disposal at landfills.
ADVANCING DIVERSITY,
EQUITY AND INCLUSION
By creating a more diverse and inclusive workplace, we’re
encouraging the collaboration and innovation required to move
our company forward. Unique perspectives, along with a breadth
and depth of knowledge, enable FirstEnergy to meet future
challenges and maximize growth opportunities.
Even with many employees working remotely, we’re focused on
promoting workplace equity and creating an open and inclusive
culture. We continue to offer opportunities for employees and
leaders to “Speak Up” about important diversity, equity and
inclusion (DEI) topics. Our leaders are committed to using this
feedback, together with responses from our annual employee
survey, to build a work environment in which everyone is
welcomed and valued for their contributions to our company’s
success. The culture we are building extends beyond compliance
and inclusivity, empowering employees to be candid, explore
creative solutions, question freely and transform mistakes into
opportunities for both individual and company growth.
Our ongoing commitment to DEI remains essential to our
forward-looking and future-building strategy. Our aspirational
goal is to achieve a 30% increase in racially and ethnically diverse
employees, both companywide and at the supervisor-and-above
leadership level, by 2025. In 2021, we increased the number of
diverse candidates on manager-and-above succession plans and
welcomed five racially and ethnically diverse new hires at the vice
president level.
Additionally, we are committed to achieving 20% of our supply
chain spend with diverse suppliers by 2025. Growing a diverse
supplier base is essential to FirstEnergy’s success, and we are
honored to have received the 2021 Women’s Business Enterprise
Center-East “Regional Council Member Done Deals” award in
recognition of our investment in supplier diversity and women-
owned businesses.
KEEPING OUR EMPLOYEES AND
COMMUNITIES SAFE
Throughout the pandemic, we’ve followed recommendations from
the Centers for Disease Control and Prevention and other medical
experts and maintained a decisive and measured response to
protect the health and safety of our employees and the public.
Whether working remotely or in person, our employees consistently
demonstrate flexibility and resiliency, finding new ways to foster
inclusivity, collaboration and innovation while safely serving our
customers and providing the power they rely on every day.
Our new Leading with Safety process was rolled out across
operations, equipping leaders with the knowledge and skills
required to support a high-performing culture where all employees
own, promote and reinforce safe behaviors. We achieved strong
performance related to our most essential safety goals and,
importantly, experienced no life-changing events.
We recognize that customers depend on our reliable service now
more than ever – and we have not wavered in our commitment
to serve them and provide value for all our stakeholders. Our
employees remain equally committed to keeping themselves,
our customers and communities safe, and our local Safety teams
will continue working together to identify potential exposures to
ensure we remain safe.
Our Employee Business Resource Groups supported FirstEnergy’s DEI
efforts with more than 140 learning and connection events in 2021.
A n n u a l R e p o r t I 5
BRINGING ENERGY TO
OUR COMMUNITIES
FirstEnergy partnered with the Cleveland Browns
to bring the thrill of “Friday Night Lights” to the
student-athletes who call Cleveland’s Bump Taylor
Field home. As the football teams from Glenville
and John Hay high schools take the field under
new lights next fall, they will also be sporting new
uniforms courtesy of FirstEnergy and the Browns.
CREATING LONG-LASTING, POSITIVE CHANGE IN OUR COMMUNITIES
FirstEnergy is committed to improving the quality of life where our customers and employees live and work, and we continue to build
critical community partnerships that enable us to make meaningful and sustainable changes across our service area.
I’m proud that FirstEnergy encourages civic engagement at all levels of the organization and celebrates employees whose good work
and good deeds brighten their communities. Through our new “Light the Way” campaign, which amplifies our employees’ dedication to
the communities we serve, we aim to re-energize their sense of pride in FirstEnergy and show how they form the heart of our company.
Whether virtually or in-person, employees volunteered over 25,000 hours, choosing to safely serve their communities despite the
ongoing pandemic.
We significantly surpassed our Harvest for Hunger Fundraising Campaign goal, with employees raising over $338,000 to support local
foodbanks, including a bonus matching gift from the FirstEnergy Foundation of $100,000. Employees also collected 8,700 pounds of
food through a food drive in April, bringing FirstEnergy’s total meal equivalent to almost 2.4 million meals.
The FirstEnergy Foundation exceeded its annual diversity, equity and inclusion investment goal with nearly 20% of the Foundation spend
in 2021 allocated to diverse organizations, or programming focused on advancing health and safety, workforce development, educational,
and social justice initiatives for diverse communities.
LIGHTING THE WAY TO FUTURE SUCCESS
I’m proud of our employees and appreciate their strong performance, resilience and unwavering dedication to our customers and each
other. I’m also excited to welcome several talented new leaders, who bring fresh perspectives and valuable experience to FirstEnergy.
As he completes his tenure as non-executive chairman of FirstEnergy’s Board of Directors, I also wish to express my sincere appreciation
to Don Misheff and the other outgoing directors for their expertise and guidance throughout this time of pivotal change. I look forward to
working closely with the refreshed Board as we further transform our company into a premier utility.
Recognizing everything we’ve accomplished over the past year, I trust we’ll meet future challenges with a continued spirit of inclusivity,
innovation and collaboration – a spirit which makes FirstEnergy a company that is prepared to light the way as a forward-thinking
industry leader in the years to come.
Thank you for your continued support as FirstEnergy looks ahead into a very bright and rewarding future.
Steven E. Strah
President and Chief Executive Officer
March 18, 2022
6 I A n n u a l R e p o r t
PA
OH
NJ
MD
WV
VA
FIRSTENERGY CORPORATE PROFILE
Headquartered in Akron, Ohio, FirstEnergy is a forward-
thinking, fully regulated utility centered on integrity and
powered by a diverse team of employees committed
to making customers’ lives brighter, the environment
better and communities stronger. Our subsidiaries
are involved in the transmission, distribution and
regulated generation of electricity. Our workforce
of approximately 12,000 employees is dedicated to
integrity, safety, reliability and operational excellence.
Our 10 electric distribution companies form one of
the nation’s largest investor-owned electric systems,
based on serving more than 6 million customers across
our service territory. The company’s transmission
subsidiaries operate approximately 24,000 miles of
transmission lines connecting the Midwest and Mid-
Atlantic regions. FirstEnergy’s Mon Power subsidiary
controls 3,580 megawatts of generating capacity,
primarily from two regulated coal plants and a partial
interest in a pumped-storage hydro facility.
GENERATING FACILITIES
Regulated Coal Plants
1. Harrison Power Station
2. Fort Martin Power Station
Pumped-Storage Hydro
3. Bath County
OHIO
Ohio Edison
The Illuminating Company
Toledo Edison
PENNSYLVANIA
Met-Ed
Penelec
Penn Power
West Penn Power
WEST VIRGINIA/MARYLAND
Mon Power
Potomac Edison
NEW JERSEY
Jersey Central Power & Light
A n n u a l R e p o r t I 7
FIRSTENERGY BOARD OF DIRECTORS
Michael J. Anderson
Chairman of the board of directors
of The Andersons, Inc.
Director of FirstEnergy since 2007
James F. O’Neil III
Chief executive officer and vice
chairman of Orbital Energy Group
Director of FirstEnergy since 2017
Steven J. Demetriou
Chairman, chief executive officer
and a director of Jacobs
Engineering Group Inc.
Director of FirstEnergy since 2017
Lisa Winston Hicks
Chair of the board for MV
Transportation, Inc.
Director of FirstEnergy since 2021
Julia L. Johnson
President of NetCommunications, LLC
Director of FirstEnergy since 2011
Paul Kaleta
Retired executive vice president and
general counsel at First Solar, Inc.
Director of FirstEnergy since 2021
Jesse A. Lynn
General counsel of
Icahn Enterprises L.P.
Director of FirstEnergy since 2021
Donald T. Misheff
Retired as managing partner
of the Northeast Ohio offices of
Ernst & Young LLP
Non-executive chairman of the
FirstEnergy Board since May 2018
Director of FirstEnergy since 2012
Thomas N. Mitchell
Chairman of the World Association
of Nuclear Operators
Director of FirstEnergy since 2016
Christopher D. Pappas
Retired as president and chief
executive officer of Trinseo S.A.
Director of FirstEnergy since 2011
Luis A. Reyes
Retired as a regional administrator
of the U.S. Nuclear Regulatory
Commission
Director of FirstEnergy since 2013
John W. Somerhalder II
Vice chair and executive director of
FirstEnergy Corp.
Director of FirstEnergy since 2021
Steven E. Strah
President and chief executive officer
of FirstEnergy Corp.
Director of FirstEnergy since 2021
Andrew Teno
Portfolio manager of Icahn Capital LP
Director of FirstEnergy since 2021
Leslie M. Turner
Retired as senior vice president,
general counsel and corporate
secretary of The Hershey Company
Director of FirstEnergy since 2018
Melvin D. Williams
Retired as president of Nicor Gas
and senior vice president of
Southern Company Gas
Director of FirstEnergy since 2021
SENIOR LEADERSHIP TEAM
John W. Somerhalder II*
Vice chair and executive director
Steven E. Strah*
President and chief executive officer
Samuel L. Belcher*
Senior vice president, Operations
Antonio Fernández
Vice president and chief ethics
and compliance officer
Michelle R. Henry
Senior vice president,
Customer Experience
Hyun Park*
Senior vice president and
chief legal officer
Irene M. Prezelj
Vice president, Investor Relations
and Communications
K. Jon Taylor*
Senior vice president and chief
financial officer and Strategy
Christine L. Walker*
Senior vice president, chief human
resources officer and Corporate
Services
* Indicates an Executive Officer of FirstEnergy. More detailed information on the principal
occupation or employment of each of FirstEnergy’s Executive Officers and the principal
business of any organization by which FirstEnergy Executive Officers are employed may
be found on page 113 of this report.
Dear Shareholders:
In 2021, your company achieved
strong financial and operational results
while implementing transformative
organizational and cultural initiatives.
On behalf of your Board of Directors,
I thank the leadership team, whose
performance, resilience and dedication to our employees and customers
remained constant as it navigated a rapidly changing landscape.
Your Board continues to support FirstEnergy through this process,
providing oversight and guidance to ensure business practices
align with your company’s Mission and Core Values. We commend
last year’s progress on ESG-related initiatives, particularly the
management team’s efforts to build a best-in-class ethics and
compliance program that sets an integrity-focused tone at the
highest levels of your company. With dedicated employees
supported by strong governance from the Board, established leaders
and key new executive hires, FirstEnergy is poised to become a more
innovative, resilient and industry-leading organization.
FirstEnergy provided investors with a total shareholder return of
41.8% for 2021, ranking it second among EEI’s 39-member index.
We recognize how important the dividend is to our shareholders.
Your Board maintained the annual dividend rate of $1.56 per share
of outstanding common stock in 2021. While the dividend is subject
to quarterly board review, it is our objective to hold this rate in 2022
and resume dividend growth within our targeted payout ratio as
earnings increase.
To best support FirstEnergy’s continued success, your Board of
Directors is composed of a diverse slate of individuals, representing
a wide breadth of knowledge, skills and perspectives. Last May, we
welcomed Melvin Williams, who brings decades of utility experience,
including operations, leadership development and customer
engagement. In July, the Board expanded to include Paul Kaleta and
Lisa Winston Hicks, who both offer critical legal expertise.
These new directors complement the Board’s impressive mix of
industry, leadership and governance experience, ensuring it will
continue to serve stakeholders’ best interests. To further refresh
the Board, several longtime members will not stand for reelection
at the 2022 Annual Meeting of Shareholders: Michael J. Anderson,
Julia L. Johnson, Thomas N. Mitchell, Christopher D. Pappas and
Luis A. Reyes. The Board appreciates the leadership and guidance
they provided during their many years of distinguished service to
FirstEnergy and its shareholders.
I am also concluding my role as a director and as non-executive
chairman of FirstEnergy’s Board of Directors following this year’s
Annual Meeting of Shareholders. It has been a great privilege to
serve on your Board since 2012, and I’m confident your company
will continue to grow stronger under the leadership of my successor.
Your Board recognizes FirstEnergy’s growth over the past year
and looks forward to an even brighter future. Thank you for your
continued support.
Sincerely,
Donald T. Misheff
Chairman of the Board
March 18, 2022
8 I A n n u a l R e p o r t
2 0 2 1 A N N UA L R E P OR T
CONTENTS
1 ..........Glossary of Terms
5 ..........Selected Financial Data
6 ..........Management’s Discussion and Analysis
51 ..........Report of Independent Registered Public Accounting Firm
53 ..........Consolidated Statements of Income
54 ..........Consolidated Statements of Comprehensive Income
55 ..........Consolidated Balance Sheets
56 ..........Consolidated Statements of Common Stockholders’ Equity
57 ..........Consolidated Statements of Cash Flows
58 ..........Notes to the Consolidated Financial Statements
113 ..........Executive Officers as of February 16, 2022
GLOSSARY OF TERMS
The following abbreviations and acronyms are used in this report to identify FirstEnergy Corp. and its current and former
subsidiaries:
AE Supply
Allegheny Energy Supply Company, LLC, an unregulated generation subsidiary
AGC
ATSI
CEI
CES
FE
FENOC
FES
Allegheny Generating Company, a generation subsidiary of MP
American Transmission Systems, Incorporated, a subsidiary of FET, which owns and operates transmission
facilities
The Cleveland Electric Illuminating Company, an Ohio electric utility operating subsidiary
Competitive Energy Services, formerly a reportable operating segment of FirstEnergy
FirstEnergy Corp., a public utility holding company
Energy Harbor Nuclear Corp. (formerly known as FirstEnergy Nuclear Operating Company), a subsidiary of EH,
which operates NG’s nuclear generating facilities
Energy Harbor LLC. (formerly known as FirstEnergy Solutions Corp.), a subsidiary of EH, which provides energy-
related products and services
FES Debtors
FES, FENOC, FG, NG, FE Aircraft Leasing Corp., Norton Energy Storage LLC, and FGMUC
FESC
FET
FEV
FG
FirstEnergy Service Company, which provides legal, financial, and other corporate support services
FirstEnergy Transmission, LLC, the parent company of ATSI, KATCo, MAIT and TrAIL, and has a joint venture in
PATH
FirstEnergy Ventures Corp., which invests in certain unregulated enterprises and business ventures
Energy Harbor Generation LLC (formerly known as FirstEnergy Generation, LLC), a subsidiary of EH, which owns
and operates fossil generating facilities
FGMUC
FirstEnergy
FirstEnergy Generation Mansfield Unit 1 Corp., a subsidiary of FG
FirstEnergy Corp., together with its consolidated subsidiaries
Global Holding
Global Mining Holding Company, LLC, a joint venture between FEV, WMB Marketing Ventures, LLC and Pinesdale
LLC
Global Rail
Global Rail Group, LLC, a subsidiary of Global Holding that owns coal transportation operations near Roundup,
Montana
GPU
GPUN
JCP&L
KATCo
MAIT
ME
MP
NG
OE
GPU, Inc., former parent of JCP&L, ME and PN, that merged with FE on November 7, 2001
GPU Nuclear, Inc., a subsidiary of FE, which formerly operated TMI-2
Jersey Central Power & Light Company, a New Jersey electric utility operating subsidiary
Keystone Appalachian Transmission Company, a subsidiary of FET
Mid-Atlantic Interstate Transmission, LLC, a subsidiary of FET, which owns and operates transmission facilities
Metropolitan Edison Company, a Pennsylvania electric utility operating subsidiary
Monongahela Power Company, a West Virginia electric utility operating subsidiary
Energy Harbor Nuclear Generation LLC (formerly known as FirstEnergy Nuclear Generation, LLC), a subsidiary of
EH, which owns nuclear generating facilities
Ohio Edison Company, an Ohio electric utility operating subsidiary
Ohio Companies
CEI, OE and TE
PATH
Potomac-Appalachian Transmission Highline, LLC, a joint venture between FE and a subsidiary of AEP
PATH-Allegheny
PATH Allegheny Transmission Company, LLC
PATH-WV
PATH West Virginia Transmission Company, LLC
PE
Penn
The Potomac Edison Company, a Maryland and West Virginia electric utility operating subsidiary
Pennsylvania Power Company, a Pennsylvania electric utility operating subsidiary of OE
Pennsylvania Companies ME, PN, Penn and WP
PN
Pennsylvania Electric Company, a Pennsylvania electric utility operating subsidiary
Signal Peak
Signal Peak Energy, LLC, an indirect subsidiary of Global Holding that owns mining operations near Roundup,
TE
TrAIL
Montana
The Toledo Edison Company, an Ohio electric utility operating subsidiary
Trans-Allegheny Interstate Line Company, a subsidiary of FET, which owns and operates transmission facilities
Transmission Companies ATSI, MAIT and TrAIL
Utilities
WP
OE, CEI, TE, Penn, JCP&L, ME, PN, MP, PE, and WP
West Penn Power Company, a Pennsylvania electric utility operating subsidiary
1
The following abbreviations and acronyms are used to identify frequently used terms in this report:
2021 Credit Facilities Collectively,
six
the
separate
senior
unsecured
five-year syndicated revolving
credit facilities entered into by FE, FET, the
Utilities, and the Transmission Companies,
on October 18, 2021
CTA
Consolidated Tax Adjustment
Affordable Clean Energy
CWA
Clean Water Act
Accumulated Deferred Income Taxes
D.C. Circuit
American Electric Power Company, Inc.
DCPD
ACE
ADIT
AEP
AFS
AFUDC
AMI
AMT
AOCI
ARO
ARP
ASC
ASU
AYE DCD
Available-for-sale
Allowance for Funds Used During
Construction
Advance Metering Infrastructure
Alternative Minimum Tax
Accumulated Other Comprehensive Income
(Loss)
Asset Retirement Obligation
Alternative Revenue Program
Accounting Standard Codification
Accounting Standards Update
Allegheny Energy,
Restated Revised Plan
Compensation of Directors
Inc. Amended and
for Deferral of
AYE Director's Plan
Bankruptcy Court
Allegheny Energy, Inc. Non-Employee
Director Stock Plan
U.S. Bankruptcy Court in the Northern
District of Ohio in Akron
BGS
bps
Brookfield
Basic Generation Service
Basis points
North American Transmission Company II
LLC, a controlled investment vehicle entity
of Brookfield Infrastructure Partners
Brookfield Guarantors Brookfield
Super-Core
Infrastructure
Partners
L.P., Brookfield Super-Core
Infrastructure Partners (NUS) L.P., and
Infrastructure
Brookfield
Partners (ER) SCSp
Super-Core
United States Court of Appeals for the District of
Columbia Circuit
FirstEnergy Corp. Deferred Compensation Plan for
Outside Directors
Delivery Capital Recovery
Distribution Modernization Rider
United States Department of Energy
Deferred Prosecution Agreement entered into on July
21, 2021 between FE and S.D. Ohio
Distribution System Improvement Charge
Default Service Plan
Deferred Tax Asset
Earnings and Profits
Electric Distribution Company
FirstEnergy Corp. Amended and Restated Executive
Deferred Compensation Plan
Electric Distribution Investment Surcharge
Energy Efficiency and Conservation
Edison Electric Institute
Electric Generation Supplier
Electric Generation Units
DCR
DMR
DOE
DPA
DSIC
DSP
DTA
E&P
EDC
EDCP
EDIS
EE&C
EEI
EGS
EGU
EH
Energy Harbor Corp.
CAA
CBA
CCR
CERCLA
CFIUS
CFL
CFR
CO2
Clean Air Act
EmPOWER
Maryland
EmPOWER Maryland Energy Efficiency Act
Collective Bargaining Agreement
ENEC
Expanded Net Energy Cost
Coal Combustion Residuals
Comprehensive Environmental Response,
Compensation, and Liability Act of 1980
Committee on Foreign Investments in the
United States
Compact Fluorescent Light
EPA
EPS
ERO
ESG
United States Environmental Protection Agency
Earnings per Share
Electric Reliability Organization
Environmental, Social, Corporate Governance
Code of Federal Regulations
ESP IV
Electric Security Plan IV
Carbon Dioxide
Exchange Act
Securities and Exchange Act of 1934, as amended
Code of Business
Conduct
The FirstEnergy Code of Business Conduct
and Ethics as approved by the FE Board on
July 20, 2021
COVID-19
Coronavirus disease
EPA's Clean Power Plan
Facebook®
Facebook is a registered trademark of Facebook, Inc.
FASB
FCA
Financial Accounting Standards Board
Financial Conduct Authority
Cross-State Air Pollution Rule
FE Board
FE Board of Directors
Conservation Support Rider
FE Revolving
Facility
FE and the Utilities’ former five-year syndicated
revolving credit facility, as amended, and replaced by
the 2021 Credit Facilities on October 18, 2021
2
CPP
CSAPR
CSR
FERC
Federal Energy Regulatory Committee
FES Bankruptcy
voluntary petitions
FES Debtors'
for
bankruptcy protection under Chapter 11 of
the
the U.S. Bankruptcy Code with
Bankruptcy Court
FET Board
The Board of Directors of FET
FET LLC Agreement
FET P&SA
FET Revolving
Facility
Third Amended and Restated Limited
Liability Company Operating Agreement of
FET
Purchase and Sale Agreement entered into
on November 6, 2021, by and between FE,
FET, Brookfield and Brookfield Guarantors
FET and certain of its subsidiaries’ former
five-year syndicated revolving credit facility,
as amended, and replaced by the 2021
Credit Facilities on October 18, 2021
NDT
NERC
NJBPU
NJ Rate
Counsel
NOL
NOx
Nuclear Decommissioning Trust
North American Electric Reliability Corporation
New Jersey Board of Public Utilities
New Jersey Division of Rate Counsel
Net Operating Loss
Nitrogen Oxide
Fitch Ratings Service
First Mortgage Bond
Federal Power Act
Financial Transmission Right
Accounting Principles Generally Accepted in
the United States of America
Greenhouse Gases
House Bill 6, as passed by Ohio's 133rd
General Assembly
House Bill 128, as passed by Ohio's 134th
General Assembly
ICE Benchmark Administration Limited
International Brotherhood of Electrical
Workers
FirstEnergy Corp. 2007 Incentive
Compensation Plan
FirstEnergy Corp. 2015 Incentive
Compensation Plan
FirstEnergy Corp. 2020 Incentive
Compensation Plan
Internal Revenue Service
Independent System Operator
Investment Tax Credit
Kilovolt
Kilowatt-hour
NPDES
National Pollutant Discharge Elimination System
NRC
NSR
NUG
Nuclear Regulatory Commission
New Source Review
Non-Utility Generation
NYPSC
New York State Public Service Commission
OAG
OCA
OCC
ODSA
OPEB
OPEIU
Ohio Attorney General
Office of Consumer Advocate
Ohio Consumers' Counsel
Ohio Development Service Agency
Other Post-Employment Benefits
Office and Professional Employees International
Union
OPIC
Other Paid-in Capital
OSHA
Occupational Safety and Health Administration
OVEC
PA DEP
PCRB
PIR
PJM
Ohio Valley Electric Corporation
Pennsylvania Department of Environmental
Protection
Pollution Control Revenue Bond
Phase-In Recovery Rider
PJM Interconnection, LLC
Light Emitting Diode
PJM Tariff
PJM Open Access Transmission Tariff
London Inter-Bank Offered Rate
Letter of Credit
Load Serving Entity
Long-Term Infrastructure Improvement
Plans
Maryland Public Service Commission
Manufactured Gas Plants
Midcontinent Independent System Operator,
Inc.
POLR
PPA
PPB
PPUC
PUCO
PURPA
RCRA
Provider of Last Resort
Purchase Power Agreement
Parts per Billion
Pennsylvania Public Utility Commission
Public Utilities Commission of Ohio
Public Utility Regulatory Policies Act of 1978
Resource Conservation and Recovery Act
Moody’s Investors Service, Inc.
REC
Renewable Energy Credit
Megawatt
Megawatt-hour
National Ambient Air Quality Standards
Net Asset Value
N.D. Ohio
Northern District of Ohio
Regulation FD Regulation Fair Disclosure promulgated by the SEC
ReliabilityFirst Corporation
Request for Proposal
Regional Greenhouse Gas Initiative
Return on Equity
RFC
RFP
RGGI
ROE
3
Fitch
FMB
FPA
FTR
GAAP
GHG
HB 6
HB 128
IBA
IBEW
ICP 2007
ICP 2015
ICP 2020
IRS
ISO
ITC
kV
KWH
LED
LIBOR
LOC
LSE
LTIIPs
MDPSC
MGP
MISO
Moody’s
MW
MWH
NAAQS
NAV
S.D. Ohio
Southern District of Ohio
Rich Site Summary
SREC
Solar Renewable Energy Credit
Regional Transmission Expansion Plan
Regional Transmission Organization
Societal Benefits Charge
Supreme Court of Ohio
United States Securities and Exchange
Commission
Significantly Excessive Earnings Test
Sulfur hexafluoride
State Implementation Plan(s) Under the
Clean Air Act
Special Litigation Committee of the FE
Board
SSO
SVC
S&P
Tax Act
TMI-1
TMI-2
TO
Twitter®
UWUA
Standard Service Offer
Static Var Compensator
Standard & Poor’s Ratings Service
Tax Cuts and Jobs Act adopted December 22, 2017
Three Mile Island Unit 1
Three Mile Island Unit 2
Transmission Owner
Twitter is a registered trademark of Twitter, Inc.
Utility Workers Union of America
VEPCO
Virginia Electric and Power Company
RSS
RTEP
RTO
SBC
SCOH
SEC
SEET
SF6
SIP
SLC
SO2
SOFR
SOS
Sulfur Dioxide
Secured Overnight Financing Rate
VIE
VSCC
Variable Interest Entity
Virginia State Corporation Commission
Standard Offer Service
WVPSC
Public Service Commission of West Virginia
4
COMMON STOCK
The common stock of FirstEnergy Corp. is listed on the New York Stock Exchange under the symbol “FE” and is traded on other
registered exchanges.
HOLDERS OF COMMON STOCK
There were 63,973 holders of 570,261,104 shares of FE’s common stock as of December 31, 2021, and 63,715 holders of
570,344,389 shares of FE's common stock as of January 31, 2022. FE has historically paid quarterly cash dividends on its
common stock. Dividend payments are subject to declaration by the FE Board and future dividend decisions determined by the
Board may be impacted by earnings growth, cash flows, credit metrics, risks and uncertainties of the government investigations
and other business conditions. Information regarding retained earnings available for payment of cash dividends is given in Note
9, "Capitalization," of the Notes to Consolidated Financial Statements.
SHAREHOLDER RETURN
The following graph shows the total cumulative return from a $100 investment on December 31, 2016, in FE’s common stock
compared with the total cumulative returns of EEI’s Index of Investor-Owned Electric Utility Companies and the S&P 500.
FirstEnergy had no transactions regarding purchases of FE common stock during the fourth quarter of 2021.
FirstEnergy does not have any publicly announced plan or program for share purchases.
5
Total Return Cumulative Values($100 Investment on December 31, 2016)FEEEI ElectricS&P 500201620172018201920202021$0$50$100$150$200$250$300 MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS
Forward-Looking Statements: This Form 10-K includes forward-looking statements within the meaning of the Private Securities
Litigation Reform Act of 1995 based on information currently available to management. Such statements are subject to certain
risks and uncertainties and readers are cautioned not to place undue reliance on these forward-looking statements. These
statements include declarations regarding management's intents, beliefs and current expectations. These statements typically
contain, but are not limited to, the terms “anticipate,” “potential,” “expect,” "forecast," "target," "will," "intend," “believe,” "project,"
“estimate," "plan" and similar words. Forward-looking statements involve estimates, assumptions, known and unknown risks,
uncertainties and other factors that may cause actual results, performance or achievements to be materially different from any
future results, performance or achievements expressed or implied by such forward-looking statements, which may include the
following (see Glossary of Terms for definitions of capitalized terms):
•
•
•
The potential liabilities, increased costs and unanticipated developments resulting from government investigations and
agreements, including those associated with compliance with or failure to comply with the DPA.
The risks and uncertainties associated with government investigations and audits regarding HB 6 and related matters,
including potential adverse impacts on federal or state regulatory matters, including, but not limited to, matters relating
to rates.
The risks and uncertainties associated with litigation, arbitration, mediation, and similar proceedings, particularly
regarding HB 6 related matters, including risks associated with obtaining court approval of the definitive settlement
agreement in the derivative shareholder lawsuits.
• Weather conditions, such as temperature variations and severe weather conditions, or other natural disasters affecting
•
•
•
future operating results and associated regulatory actions or outcomes in response to such conditions.
Legislative and regulatory developments, including, but not limited to, matters related to rates, compliance and
enforcement activity.
The ability to accomplish or realize anticipated benefits from our FE Forward initiative and our other strategic and
financial goals, including, but not limited to, overcoming current uncertainties and challenges associated with the
ongoing government investigations, executing our transmission and distribution investment plans, greenhouse gas
reduction goals, controlling costs, improving our credit metrics, growing earnings, strengthening our balance sheet, and
satisfying the conditions necessary to close the sale of the minority interest in FET.
The risks associated with cyber-attacks and other disruptions to our, or our vendors’, information technology system,
which may compromise our operations, and data security breaches of sensitive data, intellectual property and
proprietary or personally identifiable information.
• Mitigating exposure for remedial activities associated with retired and formerly owned electric generation assets.
•
The ability to access the public securities and other capital and credit markets in accordance with our financial plans,
the cost of such capital and overall condition of the capital and credit markets affecting us, including the increasing
number of financial institutions evaluating the impact of climate change on their investment decisions.
The extent and duration of the COVID-19 pandemic and the related impacts to our business, operations and financial
condition resulting from the outbreak of COVID-19 including, but not limited to, disruption of businesses in our
territories, additional costs, workforce impacts and governmental and regulatory responses to the pandemic, such as
moratoriums on utility disconnections and workforce vaccination mandates.
The effectiveness of our pandemic and business continuity plans, the precautionary measures we are taking on behalf
of our customers, contractors and employees, our customers’ ability to make their utility payment and the potential for
supply-chain disruptions.
Actions that may be taken by credit rating agencies that could negatively affect either our access to or terms of
financing or our financial condition and liquidity.
Changes in assumptions regarding factors such as economic conditions within our territories, the reliability of our
transmission and distribution system, or the availability of capital or other resources supporting identified transmission
and distribution investment opportunities.
Changes in customers’ demand for power, including, but not limited to, the impact of climate change or energy efficiency
and peak demand reduction mandates.
Changes in national and regional economic conditions, including recession and inflationary pressure, affecting us and/or
our customers and those vendors with which we do business.
The potential of non-compliance with debt covenants in our credit facilities.
The ability to comply with applicable reliability standards and energy efficiency and peak demand reduction mandates.
Changes to environmental laws and regulations, including, but not limited to, those related to climate change.
Changing market conditions affecting the measurement of certain liabilities and the value of assets held in our pension
trusts, or causing us to make contributions sooner, or in amounts that are larger, than currently anticipated.
Labor disruptions by our unionized workforce.
Changes to significant accounting policies.
Any changes in tax laws or regulations, or adverse tax audit results or rulings.
The risks and other factors discussed from time to time in our SEC filings.
•
•
•
•
•
•
•
•
•
•
•
•
•
•
Dividends declared from time to time on our common stock during any period may in the aggregate vary from prior periods due
to circumstances considered by the FE Board at the time of the actual declarations. A security rating is not a recommendation to
6
buy or hold securities and is subject to revision or withdrawal at any time by the assigning rating agency. Each rating should be
evaluated independently of any other rating.
These forward-looking statements are also qualified by, and should be read together with, the risk factors included in (a) Item 1A.
Risk Factors to FE's Form 10-K for the fiscal year ended December 31, 2021, filed with the SEC on February 16, 2022, (b) this
Management’s Discussion and Analysis of Financial Condition and Results of Operations, and (c) other factors discussed herein
and in FirstEnergy's other filings with the SEC. The foregoing review of factors also should not be construed as exhaustive. New
factors emerge from time to time, and it is not possible for management to predict all such factors, nor assess the impact of any
such factor on our business or the extent to which any factor, or combination of factors, may cause results to differ materially
from those contained in any forward-looking statements. We expressly disclaim any obligation to update or revise, except as
required by law, any forward-looking statements contained herein or in the information incorporated by reference as a result of
new information, future events or otherwise.
7
FIRSTENERGY CORP.
MANAGEMENT’S DISCUSSION AND ANALYSIS OF
FINANCIAL CONDITION AND RESULTS OF OPERATIONS
FIRSTENERGY’S BUSINESS
FE and its subsidiaries are principally involved in the transmission, distribution and generation of electricity through its reportable
segments, Regulated Distribution and Regulated Transmission.
The Regulated Distribution segment distributes electricity through FirstEnergy’s ten utility operating companies, serving
approximately six million customers within 65,000 square miles of Ohio, Pennsylvania, West Virginia, Maryland, New Jersey and
New York, and purchases power for its POLR, SOS, SSO and default service requirements in Ohio, Pennsylvania, New Jersey,
and Maryland. This segment also controls 3,580 MWs of regulated electric generation capacity located primarily in West Virginia
and Virginia. The segment's results reflect the costs of securing and delivering electric generation from transmission facilities to
customers, including the deferral and amortization of certain related costs.
The service areas of, and customers served by, FirstEnergy's regulated distribution utilities as of December 31, 2021, are
summarized below:
Company
Area Served
Customers Served
(In thousands)
JCP&L
OE
CEI
WP
PN
ME
PE
MP
TE
Penn
Northern, Western and East Central New Jersey
Central and Northeastern Ohio
Northeastern Ohio
Southwest, South Central and Northern Pennsylvania
Western Pennsylvania and Western New York
Eastern Pennsylvania
Western Maryland and Eastern West Virginia
Northern, Central and Southeastern West Virginia
Northwestern Ohio
Western Pennsylvania
1,152
1,064
756
735
589
583
432
396
315
170
6,192
The Regulated Transmission segment provides transmission infrastructure owned and operated by the Transmission
Companies and certain of FirstEnergy's utilities (JCP&L, MP, PE and WP) to transmit electricity from generation sources to
distribution facilities. The segment's revenues are primarily derived from forward-looking formula rates. Under forward-looking
formula rates, the revenue requirement is updated annually based on a projected rate base and projected costs, which is subject
to an annual true-up based on actual rate base and costs. The segment's results also reflect the net transmission expenses
related to the delivery of electricity on FirstEnergy's transmission facilities. On November 6, 2021, FirstEnergy, along with FET,
entered into the FET P&SA, with Brookfield and Brookfield Guarantors pursuant to which FET agreed to issue and sell to
Brookfield at the closing, and Brookfield agreed to purchase from FET, certain newly issued membership interests of FET, such
that Brookfield will own 19.9% of the issued and outstanding membership interests of FET, for a purchase price of $2.375 billion.
The transaction is subject to customary closing conditions, including approval from the FERC and review by the CFIUS.
Corporate/Other reflects corporate support and other costs not charged or attributable to the Utilities or Transmission
Companies, including FE's retained Pension and OPEB assets and liabilities of the FES Debtors, interest expense on FE’s
holding company debt and other businesses that do not constitute an operating segment. Additionally, reconciling adjustments
for the elimination of inter-segment transactions are included in Corporate/Other. As of December 31, 2021, 67 MWs of electric
generating capacity, representing AE Supply's OVEC capacity entitlement, is included in Corporate/Other. As of December 31,
2021, Corporate/Other had approximately $7.9 billion of FE holding company debt.
8
EXECUTIVE SUMMARY
FirstEnergy is a forward-thinking, electric utility centered on integrity, powered by a diverse team of employees, committed to
making customers’ lives brighter, the environment better and our communities stronger.
FirstEnergy's core values encompass what matters most to the company. They guide the decisions we make and the actions we
take. FirstEnergy's core values should inspire our actions today and shine a light on who we aspire to be in the future.
FirstEnergy Core Values:
Integrity: We always act ethically with honesty, humility and accountability.
Safety: We keep ourselves and others safe.
Diversity, Equity and Inclusion: We embrace differences, ensure every employee is treated fairly and create a culture
where everyone feels they belong.
Performance Excellence: We pursue excellence and seek opportunities for growth, innovation and continuous
improvement.
Stewardship: We positively impact our customers, communities and other stakeholders, and strive to protect the
environment.
•
•
•
•
•
Employees are encouraged and expected to have conversations with their leaders and peers about the core values and
FirstEnergy's commitment to building a culture centered on integrity.
At FirstEnergy, we are dedicated to staying true to our mission and core values. We understand the impact our company can
make in the world around us, which means pursuing initiatives and goals that align with our foundational principles, support our
ESG priorities, and positively impact our stakeholders.
To solidify our role as an industry leader, we have developed a long-term strategy with priorities that are centered on our mission
statement. These priorities reflect a strong foundation with an unrelenting customer focus that emphasizes modern experiences,
new growth and affordable energy bills, and is leading and enabling the energy transition to a clean, resilient and secure electric
grid.
We are proud of the steps we’ve already taken to demonstrate our commitment to our strategy and look forward to improving our
performance and executing on these strategic priorities.
FirstEnergy's Business
As a fully regulated electric utility, FirstEnergy is focused on stable and predictable earnings and cash flow from its Regulated
Distribution and Regulated Transmission businesses that deliver enhanced customer service and reliability.
FirstEnergy's Regulated Distribution business is comprised of a geographically and regulatory diverse collection of electric
utilities delivering customer-focused sustainable growth. This business operates in a territory of 65,000 square miles, across the
Midwest & Mid-Atlantic regions, one of the largest contiguous territories in the United States, and allows the Utilities to be
uniquely positioned for growth through investments that strengthen the grid and enable the clean energy transition, with
approximately $9 billion in investment plans (or 53% of the total FirstEnergy investment plan) from 2021 to 2025. Through its
investment plan, Regulated Distribution has improved reliability and added operating flexibility to the distribution infrastructure,
which provide benefits to the customers and communities those Utilities serve.
In addition to our investments to rebuild critical infrastructure and improve reliability, current and future distribution investment
opportunities that support our ESG and strategic priorities include:
•
•
•
•
•
•
•
Advanced Metering Infrastructure – install smart meters and related infrastructure;
Grid Modernization Investments that support distribution automation and voltage and var optimization;
Installation of electric vehicle charging stations;
Connected LED Streetlights – strategic goal to convert 100% of streetlights owned by the Utilities to smart LEDs by
2030;
Alternative Generation that lowers our carbon footprint;
Information Systems – enhance our core information infrastructure of our distribution systems; and
Supporting economic development to attract new business.
FirstEnergy's Regulated Transmission business is a premier, high quality transmission business, with over 24,000 miles of
transmission lines in operation and one of the largest transmission systems in PJM. The Transmission Companies and certain of
FirstEnergy's utilities (JCP&L, MP, PE and WP) are focused on "Energizing the Future" with investments that support clean-
9
energy, improve grid reliability and resiliency and support a carbon neutral future. "Energizing the Future" is the centerpiece of
FirstEnergy’s regulated investment strategy with all investments recovered under FERC-regulated forward-looking formula rates,
and approximately $8 billion in investment plans (or 45% of the total FirstEnergy investment plan) from 2021 to 2025. FirstEnergy
believes there are incremental investment opportunities for its existing transmission infrastructure of over $20 billion beyond
those identified through 2025, which are expected to strengthen grid and cyber-security and make the transmission system more
reliable, robust, secure and resistant to extreme weather events, with improved operational flexibility.
In addition to our Energizing the Future investments, current and future transmission investment opportunities that support our
ESG and strategic priorities include:
Transmission Asset Health Center: real-time monitoring to reduce outages and lower expenses;
Integrating digital technology to enhance equipment monitoring and lower costs;
Exploring real-time technologies: emerging technologies to enhance data collection; and
•
•
•
• Making smart investments to modernize the grid to integrate future renewables.
On November 6, 2021, FirstEnergy, along with FET, entered into the FET P&SA with Brookfield and the Brookfield Guarantors,
pursuant to which FET agreed to issue and sell to Brookfield at the closing, and Brookfield agreed to purchase from FET, certain
newly issued membership interests of FET, such that Brookfield will own 19.9% of the issued and outstanding membership
interests of FET, for a purchase price of $2.375 billion. The transaction is subject to customary closing conditions, including
approval from the FERC and review by the CFIUS and is expected to close in the second quarter of 2022.
On December 13, 2021, FE privately issued to BIP Securities II-B L.P., an affiliate of Blackstone Infrastructure Partners L.P.,
25,588,535 shares of FE’s common stock, par value $0.10 per share, at a price of $39.08 per share, representing an investment
of $1.0 billion. In addition, subject to certain regulatory approvals, FE will appoint a Blackstone Infrastructure Partners-selected
representative to the FE Board no later than the 2022 annual shareholders’ meeting.
On October 18, 2021, FE, FET, the Utilities, and the Transmission Companies entered into six separate senior unsecured five-
year syndicated revolving credit facilities. These new credit facilities provide substantial liquidity to support the Regulated
Distribution and Regulated Transmission businesses, and each of the operating companies within the businesses. See “Capital
Resources and Liquidity" below for additional details.
Together, these transactions enhance FirstEnergy's credit profile, provide funding for the strategic investments discussed above,
and address all of FirstEnergy's equity plans, with the exception of annual issuances of up to $100 million under regular dividend
reinvestment plans and employee benefit stock investment plans, through at least 2025.
FE Forward
FirstEnergy is also working to transform how it conducts business and serves its customers, to achieve value potential in a
sustainable way and help FirstEnergy achieve its strategic priorities. In February 2021, FirstEnergy announced a new initiative to
build upon FirstEnergy’s strong operations and business fundamentals and deliver immediate value and resilience, with
substantial working capital improvements and capital efficiencies ramping up through 2024. Called "FE Forward," the initiative
plays a critical first step in FirstEnergy’s transformation journey as it looks to enhance the organization, focus on performance
excellence, and refocus the investment strategy through a range of opportunities, including:
•
•
•
•
•
•
•
Align and centralize the organization into 5 strategic areas, optimize distribution operations by transitioning to 5 state-
aligned business units with fewer management layers and implement centrally-driven best practices and processes in
the areas of planning, scheduling and work management to safely improve frontline productivity and reducing the need
for contracted resources;
Formation of a Senior Vice President of Customer Experience position to drive key digital and productivity initiatives and
programs, such as self-service options that enhance and streamline the customer experience reducing call volume by
30-40%;
Deliver digital and data driven solutions through a ‘Digital Factory and Innovation Center’ and utilize advanced analytics
to optimize decision-making in operating expense and capital deployment;
Create a company-wide, cultural change roadmap to strengthen behaviors around FirstEnergy’s core values;
Deliver leadership and functional capability training to drive performance excellence and innovation;
Creation of a Vice President of Transformation Office to drive performance excellence; and
Optimize spend strategies by expanding resources and capabilities in Supply Chain areas such as strategic sourcing,
inventory management and optimized contract terms;
Since launching FE Forward in February 2021, which initially reviewed existing policies and practices, as well as the structure
and processes around how decisions are made, the initiative has since reviewed further improvement opportunities and
developed detailed, executable plans focusing on who, when, how and at what cost opportunities can be realized. In June 2021,
FE Forward began the implementation phase that focused on executing and implementing these findings and opportunities with
full-scale effort to drive value. By 2024, FE Forward is projected to generate approximately $380 million in annualized capital
expenditure efficiencies, as well as, approximately $250 million in working capital improvements by 2023. This program includes
an estimated $150 million of costs to achieve through 2023, which are expected to be self-funded through these efficiencies.
10
FirstEnergy plans to redeploy the capital expenditure efficiencies in a more diverse capital program that over the long-term,
continues to support our strategy as discussed above and using 2022 as baseline, operating expenses are projected to naturally
decline 1% annually allowing for strategic flexibility and customer affordability. FE Forward is not a downsizing effort and there
will not be any involuntary employee reductions in connection with this program. FirstEnergy expects that FE Forward will be a
significant catalyst to augment its growth potential by taking a more strategic approach to operating expenditures and reinvesting
in a more diverse capital program that over the long-term continues to support a smarter and cleaner electric grid, and maintain
affordable customer bills. Specifically, FirstEnergy currently expects to redeploy these capital efficiencies into several projects,
including, grid modernization, energy efficiency programs, smart meter and electric vehicle charging, and solar generation
investments. As part of these efforts, FirstEnergy will evaluate the appropriate cadence to initiate rates cases on a state-by-state
basis to best support FirstEnergy’s customer-focused strategic priorities.
FE Forward Expected Capital Efficiencies
and Working Capital Improvements
2021
Actual
2022
Forecast
2023
Forecast
2024
Forecast
2025
Forecast
Total
For the Years Ended December 31,
(In millions)
Gross Capital Expenditure Efficiencies
$
210 $
280 $
380 $
380 $
380 $ 1,630
Cost to Achieve (+/- 10%)
(40)
(80)
(30)
—
—
(150)
Net Capital Expenditure Efficiencies
$
170 $
200 $
350 $
380 $
380 $ 1,480
Working Capital Improvements
130
120
—
—
—
250
Total Cash Flow Improvements
$
300 $
320 $
350 $
380 $
380 $ 1,730
Climate Story
Our long-term strategy reiterates and supports our position that climate change is among the most important issues of our time,
and our commitment to doing our part to ensure a bright and sustainable future for the communities we serve. As part of our
Climate Strategy, we’re focused on enabling our customers to live more sustainably and thrive in a carbon-neutral future. This
includes transmission and distribution investments discussed above, investments in solar generation and supporting clean
energy options, our efforts towards electrifying the economy, and driving energy efficiency.
Additionally, we plan to reduce our company-wide GHG emissions within our direct operational control (Scope 1) by 30% by
2030 (from our 2019 baseline), as we work toward carbon neutrality by 2050. Key steps in reducing our emissions and improving
the sustainability of our operations include:
•
•
•
•
Replacing Aging Equipment: We are responsibly replacing aging equipment on our transmission system that contains
SF6, a greenhouse gas commonly used in electric utility equipment;
Electrifying our Vehicle Fleet: We are targeting 30% electrification of our light-duty and aerial truck fleet by 2030 and
100% electrification by 2050. To reach our electrification goal, we’ve committed to 100% electric or hybrid vehicle
purchases for our light-duty and aerial truck fleet moving forward, beginning with the first hybrid electric vehicle
additions to the fleet in 2021;
Using Generation Efficiencies and Flexibility: We are utilizing operational flexibilities, such as heat rate improvements
through equipment upgrades, operational monitoring systems, and auxiliary power reductions at our generation facilities
that will enable us to reach our interim 2030 goal of a 30% GHG reduction from 2019 levels, while continuing to provide
customers with safe and reliable electricity; and
Transitioning Away from Coal Generation: We expect to thoughtfully transition away from our regulated coal generation
fleet no later than 2050 and in 2021, FirstEnergy sought approval to construct a solar generation source of at least 50
MWs in West Virginia. Also in 2021, FirstEnergy filed plans with the WVPSC to comply with EPA ELG rules that would
keep MP’s generation plants responsibly operating beyond 2028, however, intends to begin a broad stakeholder
dialogue regarding planned operational end dates of 2035 and 2040 for Ft. Martin and Harrison, respectively, which
further supports our Climate Strategy.
Future resource plans to achieve carbon reductions, including potential changes in operations or any determination of retirement
dates of the regulated coal-fired generating facilities, will be developed by working collaboratively with regulators in West Virginia.
Determination of the useful life of the regulated coal-fired generating facilities could result in changes in depreciation, and/or
continued collection of net plant in rates after retirement, securitization, sale, impairment or regulatory disallowances. If MP is
unable to recover these costs, it could have a material adverse effect on FirstEnergy’s and/or MP’s financial condition, results of
operations, and cash flow.
11
HB 6 and Related Investigations
On July 21, 2020, a complaint and supporting affidavit containing federal criminal allegations were unsealed against the now
former Ohio House Speaker Larry Householder and other individuals and entities allegedly affiliated with Mr. Householder. Also,
on July 21, 2020, and in connection with the investigation, FirstEnergy received subpoenas for records from the U.S. Attorney’s
Office for the S.D. Ohio. FirstEnergy was not aware of the criminal allegations, affidavit or subpoenas before July 21, 2020.
On July 21, 2021, FE entered into a three-year DPA with the U.S. Attorney’s Office that, subject to court proceedings, resolves
the U.S. Attorney’s Office investigation into FirstEnergy relating to FirstEnergy’s lobbying and governmental affairs activities
concerning HB 6, which, among other things required FE to pay a monetary penalty of $230 million, which FE paid in the third
quarter of 2021. Under the DPA, FE agreed to the filing of a criminal information charging FE with one count of conspiracy to
commit honest services wire fraud. The $230 million payment will neither be recovered in rates or charged to FirstEnergy
customers nor will FirstEnergy seek any tax deduction related to such payment. Under the terms of the DPA, the criminal
information will be dismissed after FirstEnergy fully complies with its obligations under the DPA.
In addition to the subpoenas referenced above, the OAG, certain FE shareholders and FE customers filed several lawsuits
against FirstEnergy and certain current and former directors, officers and other employees, each relating to the allegations
against the now former Ohio House Speaker Larry Householder and other individuals and entities allegedly affiliated with Mr.
Householder. On February 9, 2022, FE, acting through the SLC, agreed to a settlement term sheet to resolve multiple
shareholder derivative lawsuits that were filed in the S.D. Ohio, the N.D. Ohio, and the Ohio Court of Common Pleas, Summit
County. The proposed settlement, which is subject to court approval, will fully resolve these shareholder derivative lawsuits and
includes a series of corporate governance enhancements, that is expected to result in the following:
•
•
•
•
•
•
Six members of the FE Board, Messrs. Michael J. Anderson, Donald T. Misheff, Thomas N. Mitchell, Christopher D.
Pappas and Luis A. Reyes, and Ms. Julia L. Johnson, will not stand for re-election at FE’s 2022 annual shareholder
meeting;
A special FE Board committee of at least three recently appointed independent directors will be formed to initiate a
review process of the current senior executive team, to begin within 30 days of the 2022 annual shareholder meeting;
The FE Board will oversee FE’s lobbying and political activities, including periodically reviewing and approving political
and lobbying action plans prepared by management;
The FE Board will form another committee of recently appointed independent directors to oversee the implementation
and third-party audits of the FE Board-approved action plans with respect to political and lobbying activities;
FE will implement enhanced disclosure to shareholders of political and lobbying activities, including enhanced
disclosure in its annual proxy statement; and
FE will further align financial incentives of senior executives to proactive compliance with legal and ethical obligations.
The settlement also includes a payment to FirstEnergy of $180 million, to be paid by insurance after court approval, less any
court-ordered attorney’s fees awarded to plaintiffs.
In addition, on August 10, 2020, the SEC, through its Division of Enforcement, issued an order directing an investigation of
possible securities laws violations by FE, and on September 1, 2020, issued subpoenas to FE and certain FE officers.
Subsequently, on April 28, 2021, the SEC issued an additional subpoena to FE. Further, in letters dated January 26, and
February 22, 2021, staff of FERC's Division of Investigations notified FirstEnergy that it is investigating FirstEnergy’s lobbying
and governmental affairs activities concerning HB 6.
A committee of independent members of the FE Board was put in place to direct an internal investigation related to the ongoing
government investigations. In addition, the FE Board formed a sub-committee of the Audit Committee to, together with the FE
Board, assess FirstEnergy’s compliance program and implement potential changes, as appropriate. FirstEnergy has taken
numerous steps to address challenges posed by the HB 6 investigations and improve its compliance culture, including the
termination and separation of certain senior executives, including FirstEnergy’s former Chief Executive Officer, for violations of
certain FirstEnergy policies and its code of business conduct, appointment of five new, independent directors to the FE Board in
2021, the hiring of key senior executives committed to supporting transparency and integrity, and strengthening and enhancing
FirstEnergy’s compliance culture through the following initiatives:
•
•
•
•
In March 2021, certain members of the FE Board met with FirstEnergy’s top 140 leaders to discuss expectations
regarding compliance and ethics.
Performed training on up-the-ladder reporting for the FirstEnergy Legal Department in March 2021.
In July 2021, enhanced new employee and third-party on-boarding processes to include expectations of FirstEnergy’s
code of conduct.
On July 20, 2021, the FE Board approved and adopted a new Code of Business Conduct, which:
Promotes and emphasizes FirstEnergy’s commitment to compliance and ethics;
◦
12
◦
◦
◦
Establishes a “speak up” culture in which stakeholders are encouraged to report actual or suspected Code of
Business Conduct violations without fear of retaliation;
Conforms to applicable compliance standards; and
Improves readability.
•
FirstEnergy completed additional steps toward enhancing the overall compliance program, including:
◦
◦
◦
◦
◦
Completion of the Office of Ethics & Compliance charter;
Delivered a Chief Ethics & Compliance Officer-led Code Awareness training to senior leaders and individuals
with significant roles in FirstEnergy’s control environment;
Conducted leader-led training on the Code of Business Conduct for all leaders;
Published an Ethics & Compliance Communication Plan; and
Selected and began implementation planning for a Governance, Risk and Compliance tool.
Although the outcome of the HB 6 investigations and state regulatory audits remain unknown, FirstEnergy took several proactive
steps to reduce regulatory uncertainty affecting the Ohio Companies:
•
•
•
•
On January 31, 2021, FirstEnergy reached a partial settlement with the OAG and other parties regarding decoupling.
While the partial settlement with the OAG focused specifically on decoupling, the Ohio Companies elected to forego
recovery of lost distribution revenue.
On March 31, 2021, FirstEnergy announced that the Ohio Companies would refund to customers amounts previously
collected under the decoupling mechanism, with interest, which totals approximately $27 million. On July 7, 2021, the
PUCO approved the Ohio Companies’ proposal, and the amounts previously collected were refunded to customers in
August 2021.
Also on March 31, 2021, the Ohio Governor signed HB 128, which, among other things, repealed parts of HB 6, the
legislation that established support for nuclear energy supply in Ohio, provided for a decoupling mechanism for electric
utilities, and provided for the ending of current energy efficiency program mandates.
On November 1, 2021, the Ohio Companies, together with the OCC, PUCO Staff, and several other signatories,
entered into a unanimous Stipulation and Recommendation (Ohio Stipulation) with the intent of resolving the ongoing
energy efficiency rider audits, various SEET proceedings, including the Ohio Companies’ 2017 SEET proceeding, and
the Ohio Companies’ quadrennial ESP review, each of which was pending before the PUCO. Specifically, the Ohio
Stipulation provides that the Ohio Companies’ current ESP IV passes the required statutory test for their prospective
SEET review as part of the Quadrennial Review of ESP IV, and except for limited circumstances, the signatory parties
have agreed not to challenge the Ohio Companies’ SEET return on equity calculation methodology for their 2021-2024
SEET proceedings. The Ohio Stipulation additionally affirms that: (i) the Ohio Companies’ ESP IV shall continue through
its previously authorized term of May 31, 2024; and (ii) the Ohio Companies will file their next base rate case in May
2024, and further, no signatory party will seek to adjust the Ohio Companies’ base distribution rates before that time,
except in limited circumstances. The Ohio Companies further agreed to refund $96 million to customers in connection
with the 2017-2019 SEET cases, and to provide $210 million in future rate reductions for all customers, including $80
million in 2022, $60 million in 2023, $45 million in 2024, and $25 million in 2025. The PUCO approved the 2017-2019
SEET refunds and 2022 rate reductions on December 1, 2021, and refunds began in January 2022.
Despite the many disruptions FirstEnergy is currently facing, the leadership team remains committed and focused on executing
its strategy and running the business. See “Outlook - Other Legal Proceedings” below for additional details on the government
investigations, the DPA, and subsequent litigation surrounding the investigation of HB 6. See also “Outlook - State Regulation -
Ohio” below for details on the PUCO proceeding reviewing political and charitable spending and legislative activity in response to
the investigation of HB 6. The outcome of the government investigations, PUCO proceedings, legislative activity, and any of
these lawsuits is uncertain and could have a material adverse effect on FirstEnergy’s financial condition, results of operations
and cash flows.
The Form 10-K discusses 2021 and 2020 items and year-over-year comparisons between 2021 and 2020. Discussions
of 2019 items and year-over-year comparisons between 2020 and 2019 that are not included in this Form 10-K can be found in
“Management’s Discussion and Analysis of Financial Condition and Results of Operations” in Part II, Item 7 of FirstEnergy’s
Annual Report on Form 10-K for the fiscal year ended December 31, 2020, filed with the SEC on February 10, 2021.
13
RESULTS OF OPERATIONS
The financial results discussed below include revenues and expenses from transactions among FirstEnergy’s business
segments. A reconciliation of segment financial results is provided in Note 15, "Segment Information," of the Notes to
Consolidated Financial Statements.
Net income by business segment was as follows:
(In millions, except per share
amounts)
For the Years Ended December 31,
Increase (Decrease)
2021
2020
2019
2021 vs 2020
2020 vs 2019
Net Income By Business Segment:
Regulated Distribution
Regulated Transmission
Corporate/Other
$
1,288 $
959 $
1,076 $
408
464
447
(457)
(420)
(619)
Income from Continuing Operations
$
1,239 $
1,003 $
904 $
Discontinued Operations
44
76
8
329
(56)
(37)
236
(32)
$
(117)
$
17
199
99
68
Net Income
$
1,283 $
1,079 $
912 $
204
18.9 % $
167
18.3 %
Earnings per share of common stock
Basic - Continuing Operations
$
2.27 $
1.85 $
1.69 $
0.42
$
Basic - Discontinued Operations
0.08
0.14
0.01
(0.06)
0.16
0.13
Basic - Net Income Attributable to
Common Stockholders
$
2.35 $
1.99 $
1.70 $
0.36
18.1 %
$
0.29
17.1 %
Earnings per share of common stock
Diluted - Continuing Operations
Diluted - Discontinued Operations
$
2.27 $
0.08
1.85 $
0.14
1.67 $
0.01
0.42
(0.06)
$
0.18
0.13
Diluted - Net Income Attributable to
Common Stockholders
$
2.35 $
1.99 $
1.68 $
0.36
18.1 %
$
0.31
18.5 %
14
Summary of Results of Operations — 2021 Compared with 2020
Financial results for FirstEnergy’s business segments for the years ended December 31, 2021 and 2020, were as follows:
Regulated
Distribution
Regulated
Transmission
Corporate/Other
and Reconciling
Adjustments
FirstEnergy
Consolidated
(In millions)
$
9,498 $
1,608 $
(140) $
2021 Financial Results
Revenues:
Electric
Other
Total Revenues
Operating Expenses:
Fuel
Purchased power
Other operating expenses
Provision for depreciation
Amortization of regulatory assets, net
General taxes
DPA penalty
Gain on sale of Yards Creek
Total Operating Expenses
Operating Income (Loss)
Other Income (Expense):
Miscellaneous income, net
Pension and OPEB mark-to-market adjustment
Interest expense
Capitalized financing costs
Total Other Expense
Income (Loss) Before Income Taxes (Benefits)
Income taxes (benefits)
Income (Loss) From Continuing Operations
Discontinued Operations, net of tax
213
9,711
481
2,947
2,967
911
260
789
—
(109)
8,246
1,465
399
270
(523)
41
187
1,652
364
1,288
—
10
1,618
—
—
358
325
9
248
—
—
940
678
41
31
(248)
33
(143)
535
127
408
—
(57)
(197)
—
17
(129)
66
—
36
230
—
220
77
81
(370)
1
(211)
(628)
(171)
(457)
44
10,966
166
11,132
481
2,964
3,196
1,302
269
1,073
230
(109)
9,406
517
382
(1,141)
75
(167)
1,559
320
1,239
44
1,283
(417)
1,726
Net Income (Loss)
$
1,288 $
408 $
(413) $
15
2020 Financial Results
Revenues:
Electric
Other
Total Revenues
Operating Expenses:
Fuel
Purchased power
Other operating expenses
Provision for depreciation
Amortization (deferral) of regulatory assets, net
General taxes
Total Operating Expenses
Operating Income (Loss)
Other Income (Expense):
Miscellaneous income, net
Pension and OPEB mark-to-market adjustment
Interest expense
Capitalized financing costs
Total Other Expense
Income (Loss) Before Income Taxes (Benefits)
Income taxes (benefits)
Income (Loss) From Continuing Operations
Discontinued Operations, net of tax
Regulated
Distribution
Regulated
Transmission
Corporate/Other
and Reconciling
Adjustments
FirstEnergy
Consolidated
(In millions)
$
9,130 $
1,613 $
(139) $
233
9,363
369
2,687
3,178
896
(64)
770
7,836
1,527
332
(323)
(501)
37
(455)
1,072
113
959
—
17
1,630
—
—
282
313
11
232
838
792
30
(40)
(219)
39
(190)
602
138
464
—
(64)
(203)
—
14
(169)
65
—
44
(46)
(157)
70
(114)
(345)
1
(388)
(545)
(125)
(420)
76
10,604
186
10,790
369
2,701
3,291
1,274
(53)
1,046
8,628
2,162
432
(477)
(1,065)
77
(1,033)
1,129
126
1,003
76
1,079
Net Income (Loss)
$
959 $
464 $
(344) $
16
Changes Between 2021 and
Financial Results
Increase (Decrease)
Regulated
Distribution
Regulated
Transmission
Corporate/Other
and Reconciling
Adjustments
FirstEnergy
Consolidated
Revenues:
Electric
Other
Total Revenues
Operating Expenses:
Fuel
Purchased power
Other operating expenses
Provision for depreciation
Amortization (deferral) of regulatory assets, net
General taxes
DPA penalty
Gain on sale of Yards Creek
Total Operating Expenses
Operating Income (Loss)
Other Income (Expense):
Miscellaneous income, net
Pension and OPEB mark-to-market adjustment
Interest expense
Capitalized financing costs
Total Other Expense
Income (Loss) Before Income Taxes (Benefits)
Income taxes (benefits)
Income (Loss) From Continuing Operations
Discontinued Operations, net of tax
$
368 $
(20)
348
(In millions)
(5) $
(7)
(12)
112
260
(211)
15
324
19
—
(109)
410
(62)
67
593
(22)
4
642
580
251
329
—
—
—
76
12
(2)
16
—
—
102
(114)
11
71
(29)
(6)
47
(67)
(11)
(56)
—
(1) $
7
6
—
3
40
1
—
(8)
230
—
266
(260)
7
195
(25)
—
177
(83)
(46)
(37)
(32)
Net Income (Loss)
$
329 $
(56) $
(69) $
362
(20)
342
112
263
(95)
28
322
27
230
(109)
778
(436)
85
859
(76)
(2)
866
430
194
236
(32)
204
17
Regulated Distribution — 2021 Compared with 2020
Regulated Distribution's net income increased $329 million in 2021, as compared to 2020, primarily resulting from the change in
pension and OPEB mark-to-market adjustments, higher customer demand, earnings benefits from capital investment-related
riders in Ohio and Pennsylvania and the implementation of the base distribution rate case in New Jersey, lower pension and
OPEB expenses and a reduction to a reserve previously recorded in 2010, partially offset by the refund and absence of Ohio
decoupling revenues, customer refunds associated with the PUCO-approved Ohio Stipulation, establishment of a regulatory
liability to return certain additional Tax Act savings to Pennsylvania customers, higher interest expense, and the absence of
deferred gain tax benefits recognized in 2020 that were triggered by the FES Debtors’ emergence from bankruptcy.
Revenues —
The $348 million increase in total revenues resulted from the following sources:
For the Years Ended
December 31,
Revenues by Type of Service
2021
2020
Increase
(Decrease)
(In millions)
Distribution services (1)
$
5,406 $
5,302 $
104
Generation sales:
Retail
Wholesale
Total generation sales
Other
Total Revenues
3,730
362
4,092
213
3,577
251
3,828
233
$
9,711 $
9,363 $
153
111
264
(20)
348
(1) Includes $(27) million and $43 million of ARP revenues for the years ended December 31, 2021 and 2020. Amounts for 2021 reflect amounts
the Ohio Companies refunded to customers that was previously collected under decoupling mechanisms, with interest. See “Outlook,” below for
further discussion on Ohio decoupling rates.
Distribution services revenues increased $104 million in 2021, as compared to 2020, primarily resulting from higher customer
demand and higher rates associated with riders in Ohio and Pennsylvania including the recovery of capital investment programs
and transmission expenses, partially offset by the refund and absence of Ohio decoupling revenues, the elimination of energy
efficiency mandates and energy efficiency programs in Ohio, customer refunds associated with the Ohio Stipulation, and the
expiration of a NUG contract. Distribution services' electric distribution deliveries by customer class are summarized in the
following table:
(In thousands)
For the Years Ended December 31,
Actual
Weather-Adjusted and Leap Year-
Adjusted
Electric Distribution MWH Deliveries
2021
2020
Increase
2021
2020
Residential
Commercial(1)
Industrial
Total Electric Distribution MWH Deliveries
(1) Includes street lighting.
55,624
35,599
54,027
54,978
34,811
52,034
1.2 %
55,678
2.3 %
35,744
3.8 %
54,027
56,142
35,213
51,981
145,250
141,823
2.4 %
145,449
143,336
Increase
(Decrease)
(0.8) %
1.5 %
3.9 %
1.5 %
Distribution deliveries to residential, commercial and industrial customers reflects the cancellation of the state mandated
COVID-19 stay-at-home orders and a trend in customer usage back to pre-COVID-19 levels. Residential and commercial
deliveries were also impacted by higher weather-related customer usage. Cooling degree days were 4% above 2020 and 17%
above normal, while heating degree days were flat to 2020 and 9% below normal. Increases in industrial deliveries were primarily
from the steel, manufacturing, and educational sectors.
18
The following table summarizes weather-adjusted distribution services' electric distribution deliveries compared to pre-pandemic
levels in 2019:
(In thousands)
For the Years Ended December 31,
Weather-Adjusted
Electric Distribution MWH Deliveries
2021
2019
Residential
Commercial(1)
Industrial
55,678
35,744
54,027
53,613
37,720
55,647
Total Electric Distribution MWH Deliveries
145,449
146,980
Increase
(Decrease)
3.9 %
(5.2) %
(2.9) %
(1.0) %
The following table summarizes the price and volume factors contributing to the $264 million increase in generation revenues in
2021, as compared to 2020:
Source of Change in Generation Revenues
Increase
(In millions)
$
Retail:
Change in sales volumes
Change in prices
Wholesale:
Change in sales volumes
Change in prices
Capacity revenue
Change in Generation Revenues
$
124
29
153
5
77
29
111
264
The increase in retail generation sales volumes was primarily due to higher weather-related usage and decreased customer
shopping in New Jersey and Pennsylvania. Total generation provided by alternative suppliers as a percentage of total MWH
deliveries in 2021, as compared to 2020, decreased to 46% from 47% in New Jersey and to 63% from 64% in Pennsylvania. The
increase in retail generation prices primarily resulted from higher non-shopping generation auction rates in Pennsylvania and
New Jersey, partially offset by a lower ENEC rate in West Virginia.
Wholesale generation revenues increased $111 million in 2021, as compared to 2020, primarily due to an increase in spot market
energy prices and higher capacity revenues. The difference between current wholesale generation revenues and certain energy
costs incurred are deferred for future recovery or refund, with no material impact to earnings.
Other revenues decreased $20 million in 2021, as compared to 2020, primarily due to lower pole attachment revenue and the
lower recovery of refinancing costs associated with the Ohio PIR. Costs associated with the Ohio PIR are deferred for future
recovery resulting in no material impact on earnings.
Operating Expenses —
Total operating expenses increased $410 million primarily due to the following:
•
•
Fuel expense increased $112 million in 2021, as compared to 2020, primarily due to higher unit costs and increased
generation output. Due to the ENEC, fuel expense has no material impact on current earnings.
Purchased power costs increased $260 million in 2021, as compared to 2020, primarily due to increased volumes as
described above, higher unit costs and increased capacity expenses, partially offset by the expiration of a NUG
contract.
19
Source of Change in Purchased Power
Increase
(In millions)
Purchases
Change due to unit costs
Change due to volumes
Capacity expense
Change in Purchased Power Costs
$
$
42
109
151
109
260
•
Other operating expenses decreased $211 million in 2021, as compared to 2020, primarily due to:
•
•
•
•
•
•
•
•
•
Lower storm restoration costs of $184 million, which were mostly deferred for future recovery, resulting in no
material impact on earnings.
Lower uncollectible expense of $123 million, of which $93 million was deferred for future recovery.
Lower West Virginia vegetation management spend and energy efficiency program costs of $50 million, which
are deferred for future recovery, resulting in no material impact on earnings.
Lower COVID-19 related expenses of $42 million, of which $12 million was deferred for future recovery.
Lower expense due to a $27 million reduction to a reserve previously recorded in 2010.
Higher network transmission expenses of $130 million, which are deferred for future recovery, resulting in no
material impact on earnings.
Higher operating and maintenance expenses in 2021 due to $25 million in incremental strategic spend incurred
to enhance customer reliability.
Higher vegetation management expenses of $26 million in Ohio and Pennsylvania.
Higher other operating and maintenance expenses of $34 million, primarily due to higher labor costs and lower
capital work as compared to 2020, partially offset by fewer planned outages at the regulated generation
facilities.
•
•
•
•
Depreciation expense increased $15 million in 2021, as compared to 2020, primarily due to a higher asset base,
partially offset by a reduction in accretion expense as a result of the TMI-2 transfer, which has no impact to earnings.
Net amortization of regulatory assets increased $324 million in 2021, as compared to 2020, primarily due to:
•
•
•
•
•
•
•
•
•
•
The $109 million reduction of the New Jersey deferred storm cost regulatory asset as a result of the Yards
Creek sale,
Lower deferrals of storm restoration of $174 million,
Lower uncollectible and COVID-19 related costs of $139 million,
A $96 million charge for customer refunds associated with the Ohio Stipulation,
A $61 million charge to establish a regulatory liability to return certain Tax Act savings to Pennsylvania
customers,
A $37 million decrease in deferral of accretion expense as a result of the TMI-2 transfer, partially offset by
$83 million amortization of a regulatory liability as part of the New Jersey base rate case implementation in
2021,
$61 million in higher generation-related and transmission-related deferrals,
$76 million in lower Pennsylvania smart meter amortization, and
$72 million related to lower other amortization.
General taxes increased $19 million in 2021, as compared to 2020, primarily due to higher Ohio property and sales-
related taxes.
Gain on sale of the Yards Creek Generating Facility of $109 million was netted against the New Jersey storm deferral,
as described above, resulting in no impact to earnings.
Other Expense —
Other expense decreased $642 million in 2021, as compared to 2020, primarily due to a $593 million change in pension and
OPEB mark-to-market adjustments and higher net miscellaneous income resulting from lower pension and OPEB non-service
costs, partially offset by higher interest expense from increased short-term borrowings under the former FE Revolving Facility
and long-term debt issuances since 2020.
20
Income Taxes
Regulated Distribution’s effective tax rate was 22.0% and 10.5% for 2021 and 2020, respectively. The change in the effective tax
rate was primarily due to the recognition of $52 million in deferred gains relating to prior intercompany transfers of generation
assets that were triggered by the deconsolidation of the FES Debtors from FirstEnergy’s consolidated federal income tax group
as a result of their emergence from bankruptcy in the first quarter of 2020.
Regulated Transmission — 2021 Compared with 2020
Regulated Transmission's net income decreased $56 million in 2021, as compared to 2020, primarily due to a charge resulting
from the filed ATSI settlement, higher interest expense associated with new debt issuances at FET, increased borrowings under
the former FET Revolving Facility, formula rate true-up adjustments and lower rate base at TrAIL, partially offset by the impact of
a higher rate base at ATSI and MAIT.
Revenues —
Total revenues decreased $12 million in 2021, as compared to 2020, primarily due to lower pension and OPEB expense recovery
and lower rate base at TrAIL, partially offset by the recovery of incremental operating expenses and a higher rate base at ATSI
and MAIT.
Revenues by transmission asset owner are shown in the following table:
Revenues by Transmission Asset Owner
2021
2020
Increase
(Decrease)
For the Years Ended
December 31,
ATSI
TrAIL
MAIT
JCP&L
MP, PE and WP
Total Revenues
Operating Expenses —
(In millions)
$
801 $
809 $
240
289
164
124
255
254
178
134
$
1,618 $
1,630 $
(8)
(15)
35
(14)
(10)
(12)
Total operating expenses increased $102 million in 2021, as compared to 2020, primarily due to a non-recoverable charge
resulting from the filed ATSI settlement, higher operation and maintenance costs and increased property taxes and depreciation
due to a higher asset base. Nearly all operating expenses are recovered through formula rates, resulting in no material impact on
current period earnings.
Other Expense —
Total other expense decreased $47 million in 2021, as compared to 2020, primarily due to a $71 million change in pension and
OPEB mark-to-market adjustment, partially offset by higher interest expense associated with new debt issuances at FET and
increased borrowings under the former FET Revolving Facility.
Income Taxes —
Regulated Transmission’s effective tax rate was 23.7% and 22.9% for 2021 and 2020, respectively.
Corporate/Other — 2021 Compared with 2020
Financial results from Corporate/Other and reconciling adjustments resulted in a $69 million increase in net loss for 2021
compared to 2020, primarily due to the $230 million DPA monetary penalty, higher interest expense from a higher rate on certain
FE holding company debt, higher investigation and other related costs, including a litigation reserve, lower tax benefits from the
remeasurement of West Virginia deferred income taxes resulting from a state tax law change passed in 2021, the absence of tax
benefits from accelerated amortization of certain investment tax credits recognized in 2020 and a lower gain from discontinued
operations, partially offset by a $195 million change in the pension and OPEB mark-to-market adjustment, higher returns on
investments and higher other discrete income tax benefits.
21
For the year ended December 31, 2021, FirstEnergy recorded a gain from discontinued operations, net of tax, of $44 million. The
gain was primarily due to income tax benefits from the final true-up to the worthless stock deduction and a final federal NOL
allocation between the FES Debtors and FirstEnergy resulting from the filing of the 2020 FirstEnergy federal income tax return
during 2021.
REGULATORY ASSETS AND LIABILITIES
Regulatory assets represent incurred costs that have been deferred because of their probable future recovery from customers
through regulated rates. Regulatory liabilities represent amounts that are expected to be credited to customers through future
regulated rates or amounts collected from customers for costs not yet incurred. FirstEnergy, the Utilities and the Transmission
Companies net their regulatory assets and liabilities based on federal and state jurisdictions.
Management assesses the probability of recovery of regulatory assets, and settlement of regulatory liabilities, at each balance
sheet date and whenever new events occur. Factors that may affect probability relate to changes in the regulatory environment,
issuance of a regulatory commission order or passage of new legislation. Upon material changes to these factors, where
applicable, FirstEnergy will record new regulatory assets and liabilities and will assess whether it is probable that currently
recorded regulatory assets and liabilities will be recovered or settled in future rates.
The following table provides information about the composition of net regulatory assets and liabilities as of December 31, 2021
and December 31, 2020, and the changes during the year ended December 31, 2021:
Net Regulatory Assets (Liabilities) by Source
2021
2020
Change
(In millions)
As of December 31,
Customer payables for future income taxes
$
(2,345) $
(2,369) $
Spent nuclear fuel disposal costs
Asset removal costs
Deferred transmission costs
Deferred generation costs
Deferred distribution costs
Contract valuations
Storm-related costs
Uncollectible and COVID-19 related costs
Energy efficiency program costs
New Jersey societal benefit costs
Regulatory transition costs
Vegetation management
Other
(101)
(646)
(3)
118
49
7
660
56
47
109
(18)
33
(19)
(102)
(721)
319
17
79
41
748
97
42
112
(20)
22
(9)
Net Regulatory Liabilities included on the Consolidated Balance Sheets
$
(2,053) $
(1,744) $
The following is a description of the regulatory assets and liabilities described above:
24
1
75
(322)
101
(30)
(34)
(88)
(41)
5
(3)
2
11
(10)
(309)
Customer payables for future income taxes - Reflects amounts to be recovered or refunded through future rates to
pay income taxes that become payable when rate revenue is provided to recover items such as AFUDC-equity and
depreciation of property, plant and equipment for which deferred income taxes were not recognized for ratemaking
purposes, including amounts attributable to tax rate changes such as the Tax Act. These amounts are being amortized
over the period in which the related deferred tax assets reverse, which is generally over the expected life of the
underlying asset.
Spent nuclear fuel disposal costs - Reflects amounts collected from customers, and the investment income, losses
and changes in fair value of the trusts for spent nuclear fuel disposal costs related to former nuclear generating
facilities, Oyster Creek and TMI-1.
Asset removal costs - Primarily represents the rates charged to customers that include a provision for the cost of
future activities to remove assets, including obligations for which an ARO has been recognized, that are expected to be
incurred at the time of retirement.
Deferred transmission costs - Principally represents differences between revenues earned based on actual costs for
the formula-rate Transmission Companies and the amounts billed. Amounts are recorded as a regulatory asset or
liability and recovered or refunded, respectively, in subsequent periods.
22
Deferred generation costs - Primarily relates to regulatory assets associated with the securitized recovery of certain
fuel and purchased power regulatory assets at the Ohio Companies (amortized through 2034) as well as the ENEC at
MP and PE. MP and PE recover net power supply costs, including fuel costs, purchased power costs and related
expenses, net of related market sales revenue through the ENEC. The ENEC rate is updated annually.
Deferred distribution costs - Primarily relates to the Ohio Companies' deferral of certain expenses resulting from
distribution and reliability related expenditures, including interest (amortized through 2036) in subsequent periods as
well as refunds owed to customers associated with the PUCO-approved Ohio Stipulation discussed below.
Contract valuations - Includes the amortization of purchase accounting adjustments at PE which were recorded in
connection with the Allegheny Energy, Inc. merger representing the fair value of NUG purchased power contracts
(amortized over the life of the contracts through 2030).
Storm-related costs - Relates to the deferral of storm costs, which vary by jurisdiction. Approximately $148 million and
$167 million are currently being recovered through rates as of December 31, 2021 and 2020, respectively.
Uncollectible and COVID-19 related costs - Includes the deferral of costs arising from COVID-19, including
uncollectible expenses under new and existing riders prior to the pandemic.
Energy efficiency program costs - Relates to the recovery of costs in excess of revenues associated with energy
efficiency programs including, New Jersey energy efficiency and renewable energy programs, the Pennsylvania
Companies' EE&C programs, the Ohio Companies' Demand Side Management and Energy Efficiency Rider, and PE's
EmPOWER Maryland Surcharge. Investments in certain of these energy efficiency programs earn a long-term return.
New Jersey societal benefit costs - Primarily relates to regulatory assets associated with MGP remediation, universal
service and lifeline funds, and consumer education in New Jersey.
Regulatory transition costs - Includes the recovery of PN above-market NUG costs; and JCP&L costs associated with
BGS, capacity and ancillary services, net of revenues from the sale of the committed supply in the wholesale market.
Vegetation management - Relates to regulatory assets in New Jersey and West Virginia associated with the recovery
of certain distribution vegetation management costs as well as MAIT vegetation management costs (amortized through
2024).
The following table provides information about the composition of net regulatory assets that do not earn a current return as of
December 31, 2021 and 2020, of which approximately $228 million and $195 million, respectively, are currently being recovered
through rates over varying periods, through 2068, depending on the nature of the deferral and the jurisdiction:
Regulatory Assets by Source Not Earning a
As of December 31,
Current Return
2021
2020
Change
Deferred transmission costs
Deferred generation costs
Storm-related costs
COVID-19 related costs
Regulatory transition costs
Vegetation management
Other
(in millions)
$
13 $
17 $
50
549
65
13
31
11
5
654
66
16
22
9
(4)
45
(105)
(1)
(3)
9
2
Regulatory Assets Not Earning a Current Return
$
732 $
789 $
(57)
CAPITAL RESOURCES AND LIQUIDITY
FirstEnergy’s business is capital intensive, requiring significant resources to fund operating expenses, construction and other
investment expenditures, scheduled debt maturities and interest payments, dividend payments, and potential contributions to its
pension plan.
FE and its distribution and transmission subsidiaries expect their existing sources of liquidity to remain sufficient to meet their
respective anticipated obligations. In addition to internal sources to fund liquidity and capital requirements for 2022 and beyond,
FE and its distribution and transmission subsidiaries expect to rely on external sources of funds. Short-term cash requirements
23
not met by cash provided from operations are generally satisfied through short-term borrowings. Long-term cash needs may be
met through the issuance of long-term debt by FE and certain of its distribution and transmission subsidiaries to, among other
things, fund capital expenditures and other capital-like investments, and refinance short-term and maturing long-term debt,
subject to market conditions and other factors.
Investments for 2021 and forecasts for 2022, 2023, 2024, and 2025 by business segment are included below:
Business Segment
2021
Actual
2022
Forecast
2023
Forecast (2)
2024
Forecast (2)
2025
Forecast (2)
Regulated Distribution (1)
$
1,733 $
1,780 $
1,725 $
1,775 $
(In millions)
Regulated Transmission
Corporate/Other
Total
1,055
86
1,500
70
1,600
50
1,700
50
$
2,874 $
3,350 $
3,375 $
3,525 $
3,625
1,825
1,750
50
(1) Includes capital expenditures and capital-like investments that earn a return.
(2) FirstEnergy expects to update the forecast over the period for items such as regulatory filings and
approvals and other changes.
In alignment with FirstEnergy’s strategy to invest in its Regulated Distribution and Regulated Transmission segments as a fully
regulated company, FirstEnergy is focused on maintaining balance sheet strength and flexibility. Specifically, at the regulated
businesses, regulatory authority has been obtained for various regulated distribution and transmission subsidiaries to issue and/
or refinance debt.
Any financing plans by FE or any of its consolidated subsidiaries, including the issuance of equity and debt, and the refinancing
of short-term and maturing long-term debt are subject to market conditions and other factors. No assurance can be given that
any such issuances, financing or refinancing, as the case may be, will be completed as anticipated or at all. Any delay in the
completion of financing plans could require FE or any of its consolidated subsidiaries to utilize short-term borrowing capacity,
which could impact available liquidity. In addition, FE and its consolidated subsidiaries expect to continually evaluate any planned
financings, which may result in changes from time to time.
On November 6, 2021, FirstEnergy, along with FET, entered into the FET P&SA with Brookfield and the Brookfield Guarantors,
pursuant to which FET agreed to issue and sell to Brookfield at the closing, and Brookfield agreed to purchase from FET, certain
newly issued membership interests of FET, such that Brookfield will own 19.9% of the issued and outstanding membership
interests of FET, for a purchase price of $2.375 billion. The transaction is subject to customary closing conditions, including
approval from the FERC and review by the CFIUS and is expected to close in the second quarter of 2022.
On December 13, 2021, FE privately issued to BIP Securities II-B L.P., an affiliate of Blackstone Infrastructure Partners L.P.,
25,588,535 shares of FE’s common stock, par value $0.10 per share, at a price of $39.08 per share, representing an investment
of $1.0 billion. In addition, subject to certain regulatory approvals, FE will appoint a Blackstone Infrastructure Partners-selected
representative to the FE Board no later than the 2022 annual shareholders’ meeting.
On October 18, 2021, FE, FET, the Utilities, and the Transmission Companies entered into six separate senior unsecured five-
year syndicated revolving credit facilities. These new credit facilities provide substantial liquidity to support the Regulated
Distribution and Regulated Transmission businesses, and each of the operating companies within the businesses. See “Capital
Resources and Liquidity" below for additional details.
Together, these transactions enhance FirstEnergy's credit profile, provide funding for the strategic investments discussed above,
and address all of FirstEnergy's equity plans, with the exception of annual issuances of up to $100 million under regular dividend
reinvestment plans and employee benefit stock investment plans, through at least 2025.
FirstEnergy is continuously evaluating the global COVID-19 pandemic and taking steps to mitigate known risks. FirstEnergy is
actively monitoring the continued impact COVID-19 is having on its customers’ receivable balances, which include increasing
arrears balances since the pandemic began. FirstEnergy has incurred, and it is expected to incur for the foreseeable future,
COVID-19 pandemic related expenses. COVID-19 related expenses consist of additional costs that FirstEnergy is incurring to
protect its employees, contractors and customers, and to support social distancing requirements. These costs include, but are
not limited to, new or added benefits provided to employees, the purchase of additional personal protection equipment and
disinfecting supplies, additional facility cleaning services, COVID-19 test kits, initiated programs and communications to
customers on utility response, and increased technology expenses to support remote working, where possible. The full impact on
FirstEnergy’s business from the COVID-19 pandemic, including the governmental and regulatory responses, is unknown at this
time and difficult to predict. FirstEnergy provides a critical and essential service to its customers and the health and safety of its
employees, contractors and customers is its first priority. FirstEnergy is continuously monitoring its supply chain and is working
closely with essential vendors to understand the continued impact the COVID-19 pandemic is having on its business; however,
24
FirstEnergy does not currently expect disruptions in its ability to deliver service to customers or any material impact on its capital
investment spending plan.
FirstEnergy continues to effectively manage operations during the pandemic in order to provide critical service to customers and
believes it is well positioned to manage through the economic slowdown. FirstEnergy Distribution and Transmission revenues
benefit from geographic and economic diversity across a five-state service territory, which also allows for flexibility with capital
investments and measures to maintain sufficient liquidity over the next twelve months. However, the situation remains fluid and
future impacts to FirstEnergy that are presently unknown or unanticipated may occur. Furthermore, the likelihood of an impact to
FirstEnergy, and the severity of any impact that does occur, could increase the longer the global pandemic persists.
As of December 31, 2021, FirstEnergy’s net deficit in working capital (current assets less current liabilities) was primarily due to
accounts payable, current portion of long-term debt and accrued interest, taxes, and compensation and benefits. FirstEnergy
believes its cash from operations and available liquidity will be sufficient to meet its current working capital needs.
Short-Term Borrowings / Revolving Credit Facilities
On October 18, 2021, FE, FET, the Utilities, and the Transmission Companies entered into the 2021 Credit Facilities, which were
six separate senior unsecured five-year syndicated revolving credit facilities with JPMorgan Chase Bank, N.A., Mizuho Bank, Ltd.
and PNC Bank, National Association that replaced the FE Revolving Facility and the FET Revolving Facility, and provide for
aggregate commitments of $4.5 billion. The 2021 Credit Facilities are available until October 18, 2026, as follows:
FE and FET, $1.0 billion revolving credit facility;
Ohio Companies, $800 million revolving credit facility;
Pennsylvania Companies, $950 million revolving credit facility;
JCP&L, $500 million revolving credit facility;
•
•
•
•
• MP and PE, $400 million revolving credit facility; and
•
Transmission Companies, $850 million revolving credit facility.
Under the 2021 Credit Facilities, an aggregate amount of $4.5 billion is available to be borrowed, repaid and reborrowed, subject
to each borrower's respective sublimit under the respective facilities. These new credit facilities provide substantial liquidity to
support the Regulated Distribution and Regulated Transmission businesses, and each of the operating companies within the
businesses.
Borrowings under the 2021 Credit Facilities may be used for working capital and other general corporate purposes. Generally,
borrowings under each of the credit facilities are available to each borrower separately and mature on the earlier of 364 days
from the date of borrowing or the commitment termination date, as the same may be extended. Each of the 2021 Credit Facilities
contain financial covenants requiring each borrower, with the exception of FE, to maintain a consolidated debt-to-total-
capitalization ratio (as defined under each of the 2021 Credit Facilities) of no more than 65%, and 75% for FET, measured at the
end of each fiscal quarter. FE is required under its 2021 Credit Facility to maintain a consolidated interest coverage ratio of not
less than 2.50 times, measured at the end of each fiscal quarter for the last four fiscal quarters beginning with the quarter ending
December 31, 2021.
FirstEnergy’s 2021 Credit Facilities bear interest at fluctuating interest rates, primarily based on LIBOR. LIBOR tends to fluctuate
based on general interest rates, rates set by the U.S. Federal Reserve and other central banks, the supply of and demand for
credit in the London interbank market and general economic conditions. FirstEnergy has not hedged its interest rate exposure
with respect to its floating rate debt. Accordingly, FirstEnergy’s interest expense for any particular period will fluctuate based on
LIBOR and other variable interest rates. On July 27, 2017, the FCA (the authority that regulates LIBOR) announced that it
intends to stop compelling banks to submit rates for the calculation of LIBOR after 2021. Subsequently, on March 5, 2021, IBA
(the entity that calculates and publishes LIBOR) and FCA made public statements regarding the future cessation of LIBOR.
According to the FCA, IBA will permanently cease to publish each of the LIBOR settings on either December 31, 2021 or June
30, 2023. IBA did not identify any successor administrator in its announcement. The announced final publication date for 1-week
and 2-month LIBOR settings and all settings for non-USD LIBOR was December 31, 2021. The announced final publication date
for overnight, 1-month, 3-month, 6-month and 12-month LIBOR settings is June 30, 2023. It is unclear whether new methods of
calculating LIBOR will be established such that it continues to exist after such end dates, and there is considerable uncertainty
regarding the publication or representativeness of LIBOR beyond such end dates. The U.S. Federal Reserve, in conjunction with
the Alternative Reference Rates Committee, is seeking to replace U.S. dollar LIBOR with a newly created index, SOFR,
calculated based on repurchase agreements backed by treasury securities. FirstEnergy’s 2021 Credit Facilities provide a
mechanism to automatically transition to a SOFR-based benchmark when all United States dollar LIBOR settings are no longer
provided or are no longer representative. In addition, FirstEnergy’s 2021 Credit Facilities provide an option for the applicable
borrower and lender to jointly elect to transition early to a SOFR-based benchmark, or in certain circumstances, an alternative
benchmark replacement. It is not possible to predict the effect of these changes, other reforms or the establishment of alternative
reference rates in the United Kingdom, the United States or elsewhere. To the extent these interest rates increase, interest
expense will increase. If sources of capital for us are reduced, capital costs could increase materially. Restricted access to
capital markets and/or increased borrowing costs could have an adverse effect on FirstEnergy’s results of operations, cash flows,
financial condition and liquidity.
25
FirstEnergy had no outstanding short-term borrowings as of December 31, 2021 and $2.2 billion of outstanding short-term
borrowings as of December 31, 2020. FirstEnergy’s available liquidity from external sources as of February 14, 2022, was as
follows:
Revolving Credit Facilities
Maturity
Commitment
Available
Liquidity
FE and FET
Ohio Companies
October 2026 $
1,000 $
(In millions)
October 2026
Pennsylvania Companies
October 2026
JCP&L
MP and PE
October 2026
October 2026
Transmission Companies
October 2026
800
950
500
400
850
Subtotal $
4,500 $
Cash and Cash equivalents
—
Total $
4,500 $
997
800
950
499
400
850
4,496
579
5,075
The following table summarizes the limitations of each individual entity on short-term indebtedness applicable to each borrower
under current regulatory approvals and applicable statutory and/or charter limitations as of December 31, 2021:
Individual Borrower
FE and FET
Regulatory and Other Short-
Term Debt Limitations
(In millions)
N/A
OE, CEI, JCP&L, ME, MP, and ATSI
$
TE and PN
WP
PE
Penn
TrAIL and MAIT
500 (1)
300 (1)
200 (1)
150 (1)
100 (1)
400 (1)
1.
Includes amounts which may be borrowed under the regulated companies' money pool.
Subject to each borrower's sublimit, the amounts noted below are available for the issuance of LOCs (subject to borrowings
drawn under the 2021 Credit Facilities) expiring up to one year from the date of issuance. The stated amount of outstanding
LOCs will count against total commitments available under each of the 2021 Credit Facilities and against the applicable
borrower's borrowing sublimit. As of December 31, 2021, FirstEnergy had $4 million in outstanding LOCs.
Revolving Credit Facility
LOC Availability
(In millions)
$
FE and FET
Ohio Companies
Pennsylvania Companies
JCP&L
MP and PE
Transmission Companies
100
150
200
100
100
200
The 2021 Credit Facilities do not contain provisions that restrict the ability to borrow or accelerate payment of outstanding
advances in the event of any change in credit ratings of the borrowers. Pricing is defined in “pricing grids,” whereby the cost of
funds borrowed under the 2021 Credit Facilities are related to the credit ratings of the company borrowing the funds. Additionally,
borrowings under each of the 2021 Credit Facilities are subject to the usual and customary provisions for acceleration upon the
occurrence of events of default, including a cross-default for other indebtedness in excess of $100 million.
As of December 31, 2021, the borrowers were in compliance with the applicable interest coverage and debt-to-total-capitalization
ratio covenants in each case as defined under the respective 2021 Credit Facilities.
26
FirstEnergy Money Pools
FirstEnergy’s utility operating subsidiary companies also have the ability to borrow from each other and FE to meet their short-
term working capital requirements. Similar but separate arrangements exist among FirstEnergy’s unregulated companies with AE
Supply, FE, FET, FEV and certain other unregulated subsidiaries. FESC administers these money pools and tracks surplus funds
of FE and the respective regulated and unregulated subsidiaries, as the case may be, as well as proceeds available from bank
borrowings. Companies receiving a loan under the money pool agreements must repay the principal amount of the loan, together
with accrued interest, within 364 days of borrowing the funds. The rate of interest is the same for each company receiving a loan
from their respective pool and is based on the average cost of funds available through the pool. The average interest rate for
borrowings in 2021 was 1.01% per annum for the regulated companies’ money pool and 0.60% per annum for the unregulated
companies’ money pool.
Long-Term Debt Capacity
FE's and its subsidiaries' access to capital markets and costs of financing are influenced by the credit ratings of their securities.
The following table displays FE’s and its subsidiaries’ credit ratings as of February 14, 2022:
Corporate Credit Rating
Senior Secured
Senior Unsecured
Issuer
FE
S&P Moody’s
BBB-
Ba1
AGC
ATSI
CEI
FET
JCP&L
ME
MAIT
MP
OE
PN
Penn
PE
TE
TrAIL
WP
BB+
BBB
BBB
BBB-
BBB
BBB
BBB
BBB
BBB
BBB
BBB
BBB
BBB
BBB
BBB
Baa2
A3
Baa2
Baa2
A3
A3
A3
Baa2
A3
Baa1
A3
Baa2
Baa1
A3
A3
Fitch
BB+
BBB-
BBB-
BBB-
BB+
BBB-
BBB-
BBB-
BBB-
BBB-
BBB-
BBB-
BBB-
BBB-
BBB-
BBB-
(1) S = Stable, N = Negative, P = Positive
S&P Moody’s
—
—
—
A-
—
—
—
—
A-
A-
—
A-
A-
A-
—
A-
—
—
—
A3
—
—
—
—
A3
A1
—
A1
A3
A2
—
A1
Fitch
—
S&P Moody’s
BB+
Ba1
Fitch
BB+
—
—
BBB+
—
—
—
—
BBB+
BBB+
—
—
BBB
BBB
BB+
BBB
BBB
BBB
BBB
BBB
BBB
BBB+ —
BBB+ —
BBB+ —
—
BBB
BBB+
—
—
A3
Baa2
Baa2
A3
A3
A3
Baa2
A3
Baa1
—
—
—
A3
—
—
BBB
BBB
BB+
BBB
BBB
BBB
—
BBB
BBB
—
—
—
BBB
—
Outlook/CreditWatch (1)
Fitch
S&P Moody’s
P
S
P
S
S
S
S
S
S
S
S
S
S
S
S
S
S
S
S
S
N
S
S
S
S
S
S
S
S
S
N
S
S
P
P
P
P
P
P
P
P
P
P
P
P
P
P
P
On July 23, 2021, S&P revised the CreditWatch implications to positive from negative on the ratings of FE and its subsidiaries.
On July 27, 2021, Moody’s revised the outlook for FE and FET to stable from negative.
On August 25, 2021, Fitch revised the outlook of FE and its subsidiaries to stable from negative.
On October 19, 2021, S&P issued a one-notch upgrade to all applicable ratings for the following subsidiaries: ATSI, CEI, JCP&L,
ME, MAIT, MP, OE, PN, Penn, PE, TE, TrAIL, and WP. The CreditWatch positive designation on FE and all subsidiaries is
unchanged. The ratings of FE and FET were affirmed.
On November 8, 2021, Moody's outlook for FE was revised from stable to positive. OE’s outlook was revised from negative to
stable, while CEI and TE’s outlook remains negative.
Also on November 8, 2021, S&P issued a one-notch upgrade to all applicable ratings and the CreditWatch positive outlook on FE
and all subsidiaries was revised to stable.
On November 12, 2021, Fitch's Outlook for FE and all subsidiaries was revised from stable to positive.
The applicable undrawn and drawn margin on the 2021 Credit Facilities are subject to ratings based pricing grids. The applicable
fee paid on the undrawn commitments under the 2021 Credit Facilities are based on each borrower's senior unsecured non-
27
credit enhanced debt ratings as determined by S&P and Moody’s. The fee paid on actual borrowings are determined based on
each borrower’s senior unsecured non-credit enhanced debt ratings as determined by S&P and Moody’s.
The interest rate payable on approximately $3.0 billion in FE’s senior unsecured notes are subject to adjustments from time to
time if the ratings on the notes from any one or more of S&P, Moody’s and Fitch decreases to a rating set forth in the applicable
governing documents. Generally a one-notch downgrade by the applicable rating agency may result in a 25 basis points coupon
rate increase beginning at BB, Ba1, and BB+ for S&P, Moody’s and Fitch, respectively, to the extent such rating is applicable to
the series of outstanding senior unsecured notes, during the next interest period, subject to an aggregate cap of 2% from
issuance interest rate.
FE's debt capacity is subject to the consolidated interest coverage ratio in the 2021 Credit Facilities. As of December 31, 2021,
FirstEnergy could incur approximately $880 million of incremental interest expense or incur a $2.2 billion reduction to the
consolidated interest coverage earnings numerator, as defined under the covenant, and FE would remain within the limitations of
the financial covenant required by the 2021 Credit Facilities.
Cash Requirements and Commitments
FirstEnergy has certain obligations and commitments to make future payments under contracts, including contracts executed in
connection with certain of the planned construction expenditures.
As of December 31, 2021 (Undiscounted):
Total
2022
2023-2024
(In millions)
2025-2026
Thereafter
Long-term debt(1)
Interest on long-term debt
Operating leases(2)
Finance leases(2)
Fuel and purchased power(3)
Committed investments(4)
Total
$
23,946 $
1,593 $
1,590 $
3,099 $
17,664
12,482
1,041
375
48
2,840
2,451
54
16
593
857
1,923
102
14
1,045
994
1,661
7,857
86
10
385
600
133
8
817
—
$
42,142 $
4,154 $
5,668 $
5,841 $
26,479
(1)
(2)
(3)
(4)
Excludes unamortized discounts and premiums, fair value accounting adjustments and finance leases.
See Note 7, "Leases," of the Notes to Consolidated Financial Statements.
Based on estimated annual amounts under contract with fixed or minimum quantities.
Amounts represent committed capital expenditures and other capital-like investments that earn a return.
Excluded from the table above are estimates for the cash outlays from power purchase contracts entered into by most of the
Utilities and under which they procure the power supply necessary to provide generation service to their customers who do not
choose an alternative supplier. Although actual amounts will be determined by future customer behavior and consumption levels,
management currently estimates these cash outlays will be approximately $2.8 billion in 2022.
The table above also excludes regulatory liabilities, AROs, reserves for litigation, injuries and damages and environmental
remediation since the amount and timing of the cash payments are uncertain. The table also excludes accumulated deferred
income taxes since cash payments for income taxes are determined based primarily on taxable income for each applicable fiscal
year.
On March 11, 2021, President Biden signed into law the American Rescue Plan Act of 2021, which, among other things,
extended shortfall amortization periods and modification of the interest rate stabilization rules for single-employer plans thereby
impacting funding requirements. As a result, FirstEnergy does not currently expect to have a required contribution to the pension
plan based on various assumptions including annual expected rate of returns for assets. However, FirstEnergy may elect to
contribute to the pension plan voluntarily.
Changes in Cash Position
As of December 31, 2021, FirstEnergy had $1,462 million of cash and cash equivalents and approximately $49 million of
restricted cash compared to $1,734 million of cash and cash equivalents and approximately $67 million of restricted cash as of
December 31, 2020, on the Consolidated Balance Sheets.
Cash Flows From Operating Activities
FirstEnergy's most significant sources of cash are derived from electric service provided by its distribution and transmission
operating subsidiaries. Beyond the cash settlement and tax sharing payments to the FES Debtors in 2020 and the DPA monetary
penalty in 2021, the most significant use of cash from operating activities is buying electricity to serve non-shopping customers
and paying fuel suppliers, employees, tax authorities, lenders and others for a wide range of materials and services.
28
Net cash provided from operating activities was $2,811 million during 2021, $1,423 million during 2020 and $2,467 million during
2019. Cash flows from operations increased $1,388 million in 2021 as compared with 2020. The increase is primarily due to the
absence of a $978 million cash settlement and tax sharing payment made to the FES Debtors upon their emergence in February
2020, higher distribution deliveries, impact of the distribution riders and transmission investment recovery, and improved working
capital, partially offset by the DPA monetary penalty paid in 2021. Improvements in working capital were primarily due to reduced
customer account receivables, which had grown during 2020 as a result of COVID-19 discussed above, higher cash collateral
receipts from certain competitive suppliers that serve customers that shop, and implementation of FE Forward initiatives that
optimized certain materials and supplies inventories and accounts payable payment terms.
FirstEnergy's Consolidated Statements of Cash Flows combines cash flows from discontinued operations with cash flows from
continuing operations within each cash flow category. The following table summarizes the major classes of cash flow items from
discontinued operations for the years ended December 31, 2021, 2020 and 2019:
(In millions)
CASH FLOWS FROM OPERATING ACTIVITIES:
Income from discontinued operations
Gain on disposal, net of tax
Deferred income taxes and investment tax credits, net
Cash Flows From Financing Activities
For the Years Ended December 31,
2020
2019
2021
$
44 $
76 $
(47)
—
(76)
—
8
(59)
47
Cash provided from (used for) financing activities was $(542) million, $2.6 billion, and $656 million in 2021, 2020, and 2019,
respectively. The following table summarizes new debt financing, redemptions, repayments, short-term borrowings and
dividends:
Securities Issued or Redeemed / Repaid
2021
2020
(In millions)
2019
For the Years Ended December 31,
New Issues
Unsecured notes
FMBs
Senior secured notes
Redemptions / Repayments
Unsecured notes
PCRBs
FMBs
Term loan
Senior secured notes
$
1,750 $
3,250 $
1,850
200
150
175
—
450
—
$
2,100 $
3,425 $
2,300
$
(400) $
(250) $
(725)
(74)
—
—
—
(58)
(50)
(750)
(64)
—
(1)
—
(63)
$
(532) $
(1,114) $
(789)
Common stock issuance
$
1,000 $
— $
Short-term borrowings, net
$
(2,200) $
1,200 $
—
—
Preferred stock dividend payments
Common stock dividend payments
$
$
— $
— $
(6)
(849) $
(845) $
(814)
29
During the year ended December 31, 2021, the following long-term debt was issued:
Company
Issuance
Date
Interest
Rate
Maturity
Amount
Issuance Type
Use of Proceeds
FET
3/19/2021
2.87%
2028
$500 million
Unsecured
Notes
Repay short-term borrowings under the former FET Revolving
Facility.
MP
TE
4/9/2021
3.55% (1)
2027
$200 million
FMB
Fund MP’s ongoing capital expenditures, for working capital
needs and for other general corporate purposes.
5/6/2021
2.65%
2028
$150 million
Senior
Secured Notes
Repay short-term borrowings, fund TE’s ongoing capital
expenditures and for other general corporate purposes.
MAIT
5/24/2021
4.10% (2)
2028
$150 million
JCP&L
6/10/2021
2.75%
2032
$500 million
ATSI
12/1/2021
2.65%
2032
$600 million
Unsecured
Notes
Unsecured
Notes
Repay borrowings outstanding under FirstEnergy’s regulated
company money pool,
fund MAIT’s ongoing capital
expenditures, to fund working capital and for other general
corporate purposes.
Repay $450 million of short-term debt under the former FE
Revolving Facility, storm recovery and restoration costs and
expenses, to fund JCP&L’s ongoing capital expenditures,
working capital requirements and for other general corporate
purposes.
Unsecured
Notes
Repay outstanding notes and short-term borrowings, to fund
ATSI's ongoing capital expenditures, working capital
requirements and for other general corporate purposes.
(1) New debt was issued at a premium under a previously issued bond series, resulting in an effective interest rate of 2.06%.
(2) New debt was issued at a premium under a previously issued note series, resulting in an effective interest rate of 2.55%.
In December 2021, notice of redemption was provided for all remaining $850 million of FE's 4.25% Notes, Series B, due 2023,
which was completed on January 20, 2022, and with a make-whole premium of approximately $38 million. Due to the
redemption, the $850 million in notes is included within currently payable long-term debt on the Consolidated Balance Sheets as
of December 31, 2021.
On January 27, 2022, CEI instructed its indenture trustee to provide notice of redemption for all remaining $150 million of CEI's
2.77% Senior Notes, Series A, due 2034, for redemption to occur on March 14, 2022.
Also on January 27, 2022, TE instructed its indenture trustee to provide notice of partial redemption for $25 million of TE's 2.65%
Senior Secured Notes, due 2028, for partial redemption which occurred on February 11, 2022.
Cash Flows From Investing Activities
Cash used for investing activities in 2021 principally represented cash used for property additions. The following table
summarizes investing activities for 2021, 2020 and 2019:
Cash Used for (Provided from) Investing Activities
2021
2020
(In millions)
2019
For the Years Ended December 31,
Property Additions:
Regulated Distribution
Regulated Transmission
Corporate/Other
Proceeds from sale of Yards Creek
Investments
Asset removal costs
Other
$
1,395 $
1,514 $
958
92
(155)
53
226
(10)
1,067
76
—
22
224
5
1,473
1,090
102
—
38
217
(47)
$
2,559 $
2,908 $
2,873
30
GUARANTEES AND OTHER ASSURANCES
FirstEnergy has various financial and performance guarantees and indemnifications which are issued in the normal course of
business. These contracts include performance guarantees, stand-by letters of credit, debt guarantees, surety bonds and
indemnifications. FirstEnergy enters into these arrangements to facilitate commercial transactions with third parties by enhancing
the value of the transaction to the third party. The maximum potential amount of future payments FirstEnergy and its subsidiaries
could be required to make under these guarantees as of December 31, 2021, was approximately $1.1 billion, as summarized
below:
Guarantees and Other Assurances
Maximum
Exposure
(In millions)
FE's Guarantees on Behalf of its Consolidated Subsidiaries
Deferred compensation arrangements
$
Vehicle leases
AE Supply asset sales(1)
Other
FE's Guarantees on Other Assurances
Surety Bonds
Deferred compensation arrangements
LOCs and other
512
75
15
7
609
331
136
9
476
Total Guarantees and Other Assurances
$
1,085
(1)
As a condition to closing AE Supply's transfer of Pleasants Power Station and as contemplated under the FES Bankruptcy settlement
agreement, FE has provided two guarantees for certain retained liabilities of AE Supply, the first totaling up to $15 million for certain
environmental liabilities associated with Pleasants Power Station, and the second being limited solely to environmental liabilities for the
McElroy's Run CCR impoundment facility, for which an ARO of $47 million is reflected on FirstEnergy's Consolidated Balance Sheets, and
which is not reflected on the table above.
Collateral and Contingent-Related Features
In the normal course of business, FE and its subsidiaries may enter into physical or financially settled contracts for the sale and
purchase of electric capacity, energy, fuel and emission allowances. Certain agreements contain provisions that require FE or its
subsidiaries to post collateral. This collateral may be posted in the form of cash or credit support with thresholds contingent upon
FE's or its subsidiaries' credit rating from each of the major credit rating agencies. The collateral and credit support requirements
vary by contract and by counterparty.
As of December 31, 2021, $55 million of collateral has been posted by FE or its subsidiaries and is included in Prepaid taxes and
other current assets on FirstEnergy's Consolidated Balance Sheets.
These credit-risk-related contingent features stipulate that if the subsidiary were to be downgraded or lose its investment grade
credit rating (based on its senior unsecured debt rating), it would be required to provide additional collateral. The following table
discloses the potential additional credit rating contingent contractual collateral obligations as of December 31, 2021:
Potential Collateral Obligations
Contractual Obligations for Additional Collateral
Upon Further Downgrade
Surety Bonds (collateralized amount)(1)
Total Exposure from Contractual Obligations
Utilities
and FET
FE
(In millions)
Total
$
$
44 $
57
— $
258
101 $
258 $
44
315
359
(1) Surety Bonds are not tied to a credit rating. Surety Bonds' impact assumes maximum contractual obligations, which is ordinarily 100% of the
face amount of the surety bond except with respect to $39 million of surety obligations for which the collateral obligation is capped at 60% of
the face amount, and typical obligations require 30 days to cure.
31
Other Commitments and Contingencies
FE was previously a guarantor under a $120 million syndicated senior secured term loan facility due November 12, 2024, which
Global Holding repaid during the fourth quarter of 2021, and as a result, FirstEnergy’s guarantee is no longer in effect.
MARKET RISK INFORMATION
FirstEnergy uses various market risk sensitive instruments, including derivative contracts, primarily to manage the risk of price
and interest rate fluctuations. FirstEnergy’s Enterprise Risk Management Committee, comprised of members of senior
management, provides general oversight for risk management activities throughout the company.
Commodity Price Risk
FirstEnergy has limited exposure to financial risks resulting from fluctuating commodity prices, including prices for electricity, coal
and energy transmission. FirstEnergy's Enterprise Risk Management Committee is responsible for promoting the effective design
and implementation of sound risk management programs and oversees compliance with corporate risk management policies and
established risk management practice.
The valuation of derivative contracts is based on observable market information. As of December 31, 2021, FirstEnergy has a net
asset of $8 million in non-hedge derivative contracts that are related to FTRs at certain of the Utilities. FTRs are subject to
regulatory accounting and do not impact earnings.
Equity Price Risk
As of December 31, 2021, the FirstEnergy pension plan assets were allocated approximately as follows: 35% in equity securities,
27% in fixed income securities, 7% in hedge funds, 4% in insurance-linked securities, 10% in real estate, 9% in private equity
and debt funds, and 8% in cash and short-term securities. FirstEnergy funding policy is based on actuarial computations using
the projected unit credit method. As a result of the American Rescue Plan Act of 2021, which, among other things, extended
shortfall amortization periods and modifications of the interest rate stabilization rules for single-employer plans, actual pension
investment performance returns to date and current assumptions, FirstEnergy does not currently expect to have a required
contribution to the pension plan. However, a decline in the value of pension plan assets could result in additional funding
requirements, and FirstEnergy may elect to contribute to the pension plan voluntarily. As of December 31, 2021, FirstEnergy's
OPEB plan assets were allocated approximately 51% in equity securities, 32% in fixed income securities and 17% in cash and
short-term securities. See Note 4, "Pension and Other Post-Employment Benefits," of the Notes to Consolidated Financial
Statements for additional details on FirstEnergy's pension and OPEB plans.
During 2021, FirstEnergy's pension and OPEB plan assets gained approximately 7.6% and 13.4%, respectively, as compared to
an annual expected return on plan assets of 7.5%.
Interest Rate Risk
FirstEnergy’s exposure to fluctuations in market interest rates is reduced since all debt has fixed interest rates, as noted in the
table below. FirstEnergy is subject to the inherent interest rate risks related to refinancing maturing debt by issuing new debt
securities.
Comparison of Carrying Value to Fair Value as of December 31, 2021
Year of Maturity or
Notice of Redemption
Assets:
Investments Other Than
Cash and Cash
Equivalents:
Fixed Income
2022
2023
2024
2025
2026
(In millions)
There-
after
Total
Fair
Value
$ —
$ —
$ —
$ —
$ —
$ 284
$ 284
$
284
Average interest rate
— %
— %
— %
— %
— %
1.0 %
1.0 %
Liabilities:
Long-term Debt:
Fixed rate
$ 1,593
$ 344
$ 1,246
$ 2,023
$ 1,076
$ 17,664
$ 23,946
$ 27,043
Average interest rate
4.3 %
3.7 %
4.7 %
3.8 %
3.5 %
4.5 %
4.4 %
FirstEnergy recognizes net actuarial gains or losses for its pension and OPEB plans in the fourth quarter of each fiscal year and
whenever a plan is determined to qualify for a remeasurement. A primary factor contributing to these actuarial gains and losses
32
are changes in the discount rates used to value pension and OPEB obligations as of the measurement date and the difference
between expected and actual returns on the plans’ assets.
CREDIT RISK
Credit risk is the risk that FirstEnergy would incur a loss as a result of nonperformance by counterparties of their contractual
obligations. FirstEnergy maintains credit policies and procedures with respect to counterparty credit (including requirements that
counterparties maintain specified credit ratings) and require other assurances in the form of credit support or collateral in certain
circumstance in order to limit counterparty credit risk. In addition, in response to the COVID-19 pandemic, FirstEnergy has
increased reviews of counterparties, customers and industries that have been negatively impacted, which could affect meeting
contractual obligations with FirstEnergy. FirstEnergy has concentrations of suppliers and customers among electric utilities,
financial institutions and energy marketing and trading companies. These concentrations may impact FirstEnergy's overall
exposure to credit risk, positively or negatively, as counterparties may be similarly affected by changes in economic, regulatory or
other conditions. In the event an energy supplier of the Ohio Companies, Pennsylvania Companies, JCP&L or PE defaults on its
obligation, the affected company would be required to seek replacement power in the market. In general, subject to regulatory
review or other processes, it is expected that appropriate incremental costs incurred by these entities would be recoverable from
customers through applicable rate mechanisms, thereby mitigating the financial risk for these entities. FirstEnergy's credit
policies to manage credit risk include the use of an established credit approval process, daily credit mitigation provisions, such as
margin, prepayment or collateral requirements, and surveys to determine negative impacts to essential vendors as a result of the
COVID-19 pandemic. FirstEnergy and its subsidiaries may request additional credit assurance, in certain circumstances, in the
event that the counterparties' credit ratings fall below investment grade, their tangible net worth falls below specified percentages
or their exposures exceed an established credit limit.
PHYSICAL SECURITY AND CYBERSECURITY RISK
FirstEnergy is committed to protecting its customers, employees, facilities, and the ongoing reliability of its electric system.
FirstEnergy works closely with state and federal agencies and its peers in the electric utility industry to identify physical and cyber
security risks, exchange information, and put safeguards in place to comply with strict reliability and security standards. From a
security standpoint, no other industry – including gas pipelines – is as heavily regulated as the electric utility sector. FirstEnergy
has comprehensive cyber and physical security plans in place but does not publicly disclose details about these measures that
could aid those who want to harm its customers, employees, facilities and the ongoing reliability of its electric system.
The FE Board has identified cybersecurity as a key enterprise risk and prioritizes the mitigation of this risk. The FE Board
receives cybersecurity updates from FirstEnergy's Information Technology organization at each of its regularly scheduled
meetings. The Audit Committee reviews FirstEnergy's cybersecurity risk management practices and performance, primarily
through reports provided by management. The Audit Committee also reviews and discusses with management the steps taken to
monitor, control, and mitigate such exposure. Among other things, these reports have focused on incident response management
and recent cyber risk and cybersecurity developments.
Security enhancements are also a key component of FirstEnergy’s Energizing the Future transmission investment program.
FirstEnergy invests heavily in sophisticated and layered security measures that use both technology and hard defenses to
protect critical transmission facilities and its digital communications networks.
Despite security measures and safeguards FirstEnergy has employed, including certain measures implemented pursuant to
mandatory NERC Critical Infrastructure Protection standards, its infrastructure may be increasingly vulnerable to such attacks as
a result of the rapidly evolving and increasingly sophisticated means by which attempts to defeat security measures and gain
access to information technology systems may be made. Also, FirstEnergy, or its vendors and service providers, may be at an
increased risk of a cyber-attack and/or data security breach due to the nature of its business.
Any such cyber incident could result in significant lost revenue, the inability to conduct critical business functions and serve
customers for a significant period of time, the use of significant management resources, legal claims or proceedings, regulatory
penalties, significant remediation costs, increased regulation, increased capital costs, increased protection costs for enhanced
cybersecurity systems or personnel, damage to FirstEnergy's reputation and/or the rendering of its internal controls ineffective,
all of which could materially adversely affect FirstEnergy's business, results of operations, financial condition and reputation.
OUTLOOK
STATE REGULATION
Each of the Utilities' retail rates, conditions of service, issuance of securities and other matters are subject to regulation in the
states in which it operates - in Maryland by the MDPSC, in New Jersey by the NJBPU, in Ohio by the PUCO, in Pennsylvania by
the PPUC, in West Virginia by the WVPSC and in New York by the NYPSC. The transmission operations of PE in Virginia, ATSI
in Ohio, and the Transmission Companies in Pennsylvania are subject to certain regulations of the VSCC, PUCO and PPUC,
respectively. In addition, under Ohio law, municipalities may regulate rates of a public utility, subject to appeal to the PUCO if not
acceptable to the utility. Further, if any of the FirstEnergy affiliates were to engage in the construction of significant new
33
transmission facilities, depending on the state, they may be required to obtain state regulatory authorization to site, construct and
operate the new transmission facility.
The following table summarizes the key terms of base distribution rate orders in effect for the Utilities as of December 31, 2021:
Company
CEI
ME(1)
MP
JCP&L
OE
PE (West Virginia)
PE (Maryland)
PN(1)
Penn(1)
TE
WP(1)
(1) Reflects filed debt/equity as final settlement/orders do not specifically include capital structure.
(2) Commission-approved settlement agreements did not disclose ROE rates.
(3) On October 28, 2020, the NJBPU approved JCP&L's distribution rate case settlement with an allowed ROE of 9.6%
and a 48.6% debt / 51.4% equity capital structure. Rates are effective for customers on November 1, 2021, but
beginning January 1, 2021, JCP&L offset the impact to customers' bills by amortizing an $86 million regulatory liability.
Allowed ROE
10.5%
Settled(2)
Settled(2)
9.6%
10.5%
Settled(2)
9.65%
Settled(2)
Settled(2)
10.5%
Settled(2)
Rates Effective
For Customers
May 2009
January 2017
February 2015
November 2021(3)
January 2009
February 2015
March 2019
January 2017
January 2017
January 2009
January 2017
Allowed Debt/
Equity
51% /49%
48.8% / 51.2%
54% / 46%
48.6% / 51.4%
51% /49%
54% / 46%
47% / 53%
47.4% /52.6%
49.9% / 50.1%
51% / 49%
49.7% / 50.3%
MARYLAND
PE operates under MDPSC approved base rates that were effective as of March 23, 2019. PE also provides SOS pursuant to a
combination of settlement agreements, MDPSC orders and regulations, and statutory provisions. SOS supply is competitively
procured in the form of rolling contracts of varying lengths through periodic auctions that are overseen by the MDPSC and a
third-party monitor. Although settlements with respect to SOS supply for PE customers have expired, service continues in the
same manner until changed by order of the MDPSC. PE recovers its costs plus a return for providing SOS.
The EmPOWER Maryland program requires each electric utility to file a plan to reduce electric consumption and demand 0.2%
per year, up to the ultimate goal of 2% annual savings, for the duration of the 2021-2023 EmPOWER Maryland program cycles to
the extent the MDPSC determines that cost-effective programs and services are available. PE's approved 2021-2023
EmPOWER Maryland plan continues and expands upon prior years' programs for a projected total investment of approximately
$148 million over the three-year period. PE recovers program investments with a return through an annually reconciled
surcharge, with most costs subject to recovery over a five-year period with a return on the unamortized balance. Maryland law
only allows for the utility to recover lost distribution revenue attributable to energy efficiency or demand reduction programs
through a base rate case proceeding, and to date, such recovery has not been sought or obtained by PE.
In 2019, MDPSC issued an order approving PE’s 2018 base rate case filing, which among other things, approved an annual rate
increase of $6.2 million, approved three of the four EDIS programs for four years to fund enhanced service reliability programs,
directed PE to file a new depreciation study within 18 months, and ordered the filing of a new base rate case in four years to
correspond to the ending of the approved EDIS programs. Following the filing of PE’s depreciation study and subsequent filings
by the Maryland Office of the People’s Counsel and the staff of the MDPSC, the public utility law judge issued a proposed order
reducing PE’s base rates by $2.1 million. The MDPSC denied PE’s appeal of the proposed order on October 26, 2021, and the
proposed order was affirmed.
On April 9, 2020, the MDPSC issued an order allowing utilities to track and create a regulatory asset for future recovery of all
prudently incurred incremental costs arising from the COVID-19 pandemic, including incremental uncollectible expense, incurred
from the date of the Governor’s order (or earlier if the utility could show that the expenses related to suspension of service
terminations). On June 16, 2021, the MDPSC provided PE with approximately $4 million of COVID-19 relief funds that was
allocated by the Maryland General Assembly to be used to reduce certain residential customer utility account receivable
arrearages.
NEW JERSEY
JCP&L operates under NJBPU approved rates that were effective for customers as of November 1, 2021. JCP&L provides BGS
for retail customers who do not choose a third-party EGS and for customers of third-party EGSs that fail to provide the contracted
service. All New Jersey EDCs participate in this competitive BGS procurement process and recover BGS costs directly from
customers as a charge separate from base rates.
34
In December 2017, the NJBPU issued proposed rules to modify its current CTA policy in base rate cases to: (i) calculate savings
using a five-year look back from the beginning of the test year; (ii) allocate savings with 75% retained by the company and 25%
allocated to customers; and (iii) exclude transmission assets of electric distribution companies in the savings calculation. On
January 17, 2019, the NJBPU approved the proposed CTA rules with no changes. On May 17, 2019, the NJ Rate Counsel filed
an appeal with the Appellate Division of the Superior Court of New Jersey and on June 7, 2021, the Superior Court issued an
order reversing the NJBPU’s CTA rules and remanded the case back to the NJBPU. Specifically, the Court’s ruling requires
100% of the CTA savings to be credited to customers in lieu of the NJBPU’s current policy requiring 25%. On December 6, 2021,
the NJBPU issued proposed amended rules modifying its current CTA policy in base rate cases consistent with the Superior
Court’s June 7, 2021 order. Once the proposed rules are final, they will be applied on a prospective basis in a future base rate
case, however, it is not expected to have a material adverse effect on FirstEnergy’s results or financial condition.
On February 18, 2020, JCP&L submitted a filing with the NJBPU requesting a distribution base rate increase. On October 28,
2020, the NJBPU approved a stipulated settlement between JCP&L and various parties, providing for, among other things, a $94
million annual base distribution revenues increase for JCP&L based on an ROE of 9.6%, which became effective for customers
on November 1, 2021. Between January 1, 2021 and October 31, 2021, JCP&L amortized an existing regulatory liability totaling
approximately $86 million to offset the base rate increase that otherwise would have occurred in this period. The parties also
agreed that the actual net gain from the sale of JCP&L’s interest in the Yards Creek pumped-storage hydro generation facility in
New Jersey (210 MWs), as further discussed below, be applied to reduce JCP&L’s existing regulatory asset for previously
deferred storm costs. Lastly, the parties agreed that approximately $95 million of Reliability Plus capital investment for projects
through December 31, 2020, is included in rate base effective December 31, 2020. Included in the NJBPU approved-settlement
in JCP&L’s distribution rate case on October 28, 2020, was that JCP&L will be subject to a management audit. The management
audit began at the end of May 2021 and is currently ongoing.
On April 6, 2020, JCP&L signed an asset purchase agreement with Yards Creek Energy, LLC, a subsidiary of LS Power to sell its
50% interest in the Yards Creek pumped-storage hydro generation facility. Subject to terms and conditions of the agreement, the
base purchase price is $155 million. As of December 31, 2020, assets held for sale on FirstEnergy’s Consolidated Balance
Sheets associated with the transaction consist of property, plant and equipment of $45 million, which is included in the regulated
distribution segment. On July 31, 2020, FERC approved the transfer of JCP&L’s interest in the hydroelectric operating license.
On October 8, 2020, FERC issued an order authorizing the transfer of JCP&L’s ownership interest in the hydroelectric facilities.
On October 28, 2020, the NJBPU approved the sale of Yards Creek. With the receipt of all required regulatory approvals, the
transaction was consummated on March 5, 2021 and resulted in a $109 million gain within the regulated distribution segment. As
further discussed above, the gain from the transaction was applied against and reduced JCP&L’s existing regulatory asset for
previously deferred storm costs and, as a result, was offset by expense in the “Amortization of regulatory assets, net”, line on the
Consolidated Statements of Income, resulting in no earnings impact to FirstEnergy or JCP&L.
On August 27, 2020, JCP&L filed an AMI Program with the NJBPU, which proposed the deployment of approximately 1.2 million
advanced meters over a three-year period beginning on January 1, 2023, at a total cost of approximately $418 million, including
the pre-deployment phase. The then proposed 3-year deployment was part of the 20-year AMI Program that was projected to
cost approximately $732 million and proposed a cost recovery mechanism through a separate AMI tariff rider. On September 14,
2021, JCP&L submitted a supplemental filing, which reflected increases in the AMI Program’s costs. Under the revised AMI
Program, during the first six years of the AMI Program from 2022 through 2027, JCP&L estimates costs of $494 million,
consisting of capital expenditures of approximately $390 million, incremental operations and maintenance expenses of
approximately $73 million and cost of removal of $31 million. On February 8, 2022, JCP&L filed with the NJBPU a stipulation
entered into with the NJBPU staff, NJ Rate Counsel and others, that, pending NJBPU approval, would affirm the terms of the
revised AMI Program. JCP&L expects a NJBPU order by the end of the first quarter of 2022. The Stipulation also provided that
the revised AMI Program-related capital costs, the legacy meter stranded costs, and the operations and maintenance expense
will be deferred and placed in regulatory assets, with such amounts sought to be recovered in the JCP&L’s subsequent base rate
cases.
On June 10, 2020, the NJBPU issued an order establishing a framework for the filing of utility-run energy efficiency and peak
demand reduction programs in accordance with the New Jersey Clean Energy Act. Under the established framework, JCP&L will
recover its program investments with a return over a ten-year amortization period and its operations and maintenance expenses
on an annual basis, be eligible to receive lost revenues on energy savings that resulted from its programs and be eligible for
incentives or subject to penalties based on its annual program performance, beginning in the fifth year of its program offerings.
On September 25, 2020, JCP&L filed its energy efficiency and peak demand reduction program, which consists of 11 energy
efficiency and peak demand reduction programs and subprograms to be run from July 1, 2021, through June 30, 2024. On April
23, 2021, JCP&L filed a Stipulation of Settlement with the NJBPU for approval of recovery of lost revenues resulting from the
programs and a three-year plan including total program costs of $203 million, of which $158 million of investment is recovered
over a ten-year amortization period with a return as well as operations and maintenance expenses and financing costs of $45
million recovered on an annual basis. On April 27, 2021, the NJBPU issued an Order approving the Stipulation of Settlement.
On July 2, 2020, the NJBPU issued an order allowing New Jersey utilities to track and create a regulatory asset for future
recovery of all prudently incurred incremental costs arising from the COVID-19 pandemic beginning March 9, 2020 and
continuing until the New Jersey Governor issues an order stating that the COVID-19 pandemic is no longer in effect. New Jersey
utilities can request recovery of such regulatory asset in a stand-alone COVID-19 regulatory asset filing or future base rate case.
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On October 28, 2020, the NJBPU issued an order expanding the scope of the proceeding to examine all pandemic issues,
including recovery of the COVID-19 regulatory assets, by way of a generic proceeding. Through various executive orders issued
by the New Jersey Governor, the moratorium period was extended to December 31, 2021. On December 21, 2021, the
moratorium on residential disconnections for certain entities providing utility service was extended until March 15, 2022. The
moratorium on residential disconnections was not extended for investor-owned electric utilities such as JCP&L, but does require
that investor-owned electric public utilities offer qualifying residential customers deferred payment arrangements meeting certain
minimum criteria prior to disconnecting service.
Credit rating actions taken by S&P and Fitch on October 28, 2020 triggered a requirement from various NJBPU orders that
JCP&L file a mitigation plan, which was filed on November 5, 2020, to demonstrate that JCP&L has sufficient liquidity to meet its
BGS obligations. On December 11, 2020, the NJBPU held a public hearing on the mitigation plan. Written comments on JCP&L’s
mitigation plan were submitted on January 8, 2021.
Pursuant to an NJBPU order requiring all New Jersey electric distribution companies to file electric vehicle programs, JCP&L filed
its program on March 1, 2021. JCP&L’s proposed electric vehicle program consisted of six sub-programs, including a consumer
education and outreach initiative that would begin on January 1, 2022, and continue over a four-year period. The total proposed
budget for the electric vehicle program is approximately $50 million, of which $16 million is capital expenditures and $34 million is
for operations and maintenance expenses. JCP&L is proposing to recover the electric vehicle program costs via a non-
bypassable rate clause applicable to all distribution customer rate classes, which became effective on January 1, 2022. On May
26, 2021, a procedural schedule was set to include evidentiary hearings the week of October 18, 2021. On July 16, 2021, the
procedural schedule was extended by thirty days as requested by JCP&L to continue settlement discussions. On August 19,
2021, the presiding commissioner issued an order modifying the procedural schedule by extending the procedural schedule by
ninety days as requested by JCP&L to continue settlement discussions. On November 12, 2021, JCP&L filed a letter with the
presiding commissioner requesting a suspension of the procedural schedule in order to allow the parties to continue settlement
discussion. On November 23, 2021, the presiding commissioner entered an order suspending the procedural schedule. JCP&L
expects an order from the NJBPU by the end of the first quarter of 2022.
OHIO
The Ohio Companies operate under PUCO approved base distribution rates that became effective in 2009. The Ohio Companies
currently operate under ESP IV, effective June 1, 2016 and continuing through May 31, 2024, that continues the supply of power
to non-shopping customers at a market-based price set through an auction process. ESP IV also continues the Rider DCR,
which supports continued investment related to the distribution system for the benefit of customers, with increased revenue caps
of $20 million per year from June 1, 2019 through May 31, 2022; and $15 million per year from June 1, 2022 through May 31,
2024. In addition, ESP IV includes: (1) continuation of a base distribution rate freeze through May 31, 2024; (2) a goal across
FirstEnergy to reduce CO2 emissions by 90% below 2005 levels by 2045; and (3) contributions, totaling $51 million to: (a) fund
energy conservation programs, economic development and job retention in the Ohio Companies’ service territories; (b) establish
a fuel-fund in each of the Ohio Companies’ service territories to assist low-income customers; and (c) establish a Customer
Advisory Council to ensure preservation and growth of the competitive market in Ohio.
ESP IV further provided for the Ohio Companies to collect DMR revenues, but the SCOH reversed the PUCO’s decision to
include DMR in ESP IV. Subsequently, the PUCO entered an order directing the Ohio Companies to cease further collection
through the DMR and credit back to customers a refund of the DMR funds collected since July 2, 2019. On December 1, 2020,
the SCOH reversed the PUCO’s exclusion of the DMR revenues from the determination of the existence of significantly
excessive earnings under ESP IV for OE for calendar year 2017, and remanded the case to the PUCO with instructions to
conduct new proceedings which include the DMR revenues in the analysis, determine the threshold against which the earned
return is measured, and make other necessary determinations. As further described below, the Ohio Stipulation resolves the
Ohio Companies’ 2017 SEET proceeding.
On July 23, 2019, Ohio enacted HB 6, which included provisions supporting nuclear energy, authorizing a decoupling mechanism
for Ohio electric utilities and ending current energy efficiency program mandates. Under HB 6, the energy efficiency program
mandates, as well as Ohio electric utilities’ energy efficiency and peak demand reduction cost recovery riders, ended on
December 31, 2020, subject to final reconciliation. Third-parties have challenged the Ohio Companies’ authorization to recover
all lost distribution revenue under energy efficiency and peak demand reduction cost recovery riders. The Ohio Stipulation
resolves the issues related to lost distribution revenue with no financial impact to the Ohio Companies.
On March 31, 2021, the Ohio Governor signed HB 128, which, among other things, repealed parts of HB 6, the legislation that
established support for nuclear energy supply in Ohio, provided for a decoupling mechanism for Ohio electric utilities, and
provided for the ending of current energy efficiency program mandates. HB 128 was effective June 30, 2021. As FirstEnergy
would not have financially benefited from the mechanism to provide support to nuclear energy in Ohio, there is no expected
additional impact to FirstEnergy due to the repeal of that provision in HB 6.
As further discussed below, in connection with a partial settlement with the OAG and other parties, the Ohio Companies filed an
application with the PUCO on February 1, 2021, to set the respective decoupling riders (CSR) to zero. On February 2, 2021, the
PUCO approved the application. While the partial settlement with the OAG focused specifically on decoupling, the Ohio
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Companies elected to forego recovery of lost distribution revenue. FirstEnergy also committed to pursuing an open dialogue with
stakeholders in an appropriate manner with respect to the numerous regulatory proceedings then underway as further discussed
herein. As a result of the partial settlement, and the decision to not seek lost distribution revenue, FirstEnergy recognized a $108
million pre-tax charge ($84 million after-tax) in the fourth quarter of 2020, and $77 million (pre-tax) of which is associated with
forgoing collection of lost distribution revenue. The Ohio Stipulation affirms the Ohio Companies’ commitment to not seek
recovery of lost distribution revenue through the end of its ESP IV in May 2024.
On March 31, 2021, FirstEnergy announced that the Ohio Companies would refund to customers amounts previously collected
under decoupling, with interest, totaling approximately $27 million. On July 7, 2021, the PUCO issued an order approving the
Ohio Companies’ modified application to refund such amounts to customers and directed that all funds collected through CSR be
refunded to customers over a single billing cycle beginning August 1, 2021.
In connection with the audit of the Ohio Companies’ Rider DCR for 2017, the PUCO issued an order on June 16, 2021, directing
the Ohio Companies to prospectively discontinue capitalizing certain vegetation management costs and reduce the 2017 Rider
DCR revenue requirement by $3.7 million associated with these costs.
On September 8, 2020, the OCC filed motions in the Ohio Companies’ corporate separation audit and DMR audit dockets,
requesting the PUCO to open an investigation and management audit, hire an independent auditor, and require FirstEnergy to
show it did not improperly use money collected from consumers or violate any utility regulatory laws, rules or orders in its
activities regarding HB 6. On December 30, 2020, in response to the OCC's motion, the PUCO reopened the DMR audit docket,
and directed PUCO staff to solicit a third-party auditor and conduct a full review of the DMR to ensure funds collected from
customers through the DMR were only used for the purposes established in ESP IV. On June 2, 2021, the PUCO selected an
auditor. The auditor filed the final audit report on January 14, 2022, which made findings and recommendations. The report found
that spending of DMR revenues was not required to be tracked, and that DMR revenues, like all rider revenues, are placed into
the regulated money pool as a matter of routine, where the funds lose their identify. Therefore, the report could not suggest that
DMR funds were used definitively for direct or indirect support for grid modernization. The report also concluded that there was
no documented evidence that ties revenues from the DMR to lobbying for the passage of HB 6, but also could not rule out with
certainty uses of DMR funds to support the passage of HB 6. The report further recommended that the regulated companies'
money pool be audited more frequently and the Ohio Companies adopt formal dividend policies.
On September 15, 2020, the PUCO opened a new proceeding to review the political and charitable spending by the Ohio
Companies in support of HB 6 and the subsequent referendum effort, and directing the Ohio Companies to show cause,
demonstrating that the costs of any political or charitable spending in support of HB 6, or the subsequent referendum effort, were
not included, directly or indirectly, in any rates or charges paid by customers. The Ohio Companies initially filed a response
stating that the costs of any political or charitable spending in support of HB 6, or the subsequent referendum effort, were not
included, directly or indirectly, in any rates or charges paid by customers, but on August 6, 2021, filed a supplemental response
explaining that, in light of the facts set forth in the DPA and the findings of the Rider DCR audit report further discussed below,
political or charitable spending in support of HB 6, or the subsequent referendum effort, affected pole attachment rates paid by
approximately $15 thousand. On October 26, 2021, the OCC filed a motion requesting the PUCO to order an independent
external audit to investigate FE’s political and charitable spending related to HB 6, and to appoint an independent review panel to
retain and oversee the auditor. In November and December 2021, parties filed comments and reply comments regarding the
Ohio Companies’ original and supplemental responses to the PUCO’s September 15, 2020, show cause directive.
In connection with an ongoing audit of the Ohio Companies’ policies and procedures relating to the code of conduct rules
between affiliates, on November 4, 2020, the PUCO initiated an additional corporate separation audit as a result of the
FirstEnergy leadership transition announcement made on October 29, 2020, as further discussed below. The additional audit is
to ensure compliance by the Ohio Companies and their affiliates with corporate separation laws and the Ohio Companies’
corporate separation plan. The additional audit is for the period from November 2016 through October 2020. The final audit
report was filed on September 13, 2021. The audit report makes no findings of major non-compliance with Ohio corporate
separation requirements, minor non-compliance with eight requirements, and findings of compliance with 23 requirements.
Parties filed comments and reply comments on the audit report, and a PUCO attorney examiner has issued a procedural
schedule setting an evidentiary hearing on May 9, 2022.
In the fourth quarter of 2020, motions were filed with the PUCO requesting that the PUCO amend the Ohio Companies’ riders for
collecting the OVEC related charges required by HB 6, which the Ohio Companies are further required to remit to other Ohio
electric distribution utilities or to the State Treasurer, to provide for refunds in the event such provisions of HB 6 are repealed.
The Ohio Companies contested the motions, which are pending before the PUCO.
On December 7, 2020, the Citizens’ Utility Board of Ohio filed a complaint with the PUCO against the Ohio Companies. The
complaint alleges that the Ohio Companies’ new charges resulting from HB 6, and any increased rates resulting from
proceedings over which the former PUCO Chairman presided, are unjust and unreasonable, and that the Ohio Companies
violated Ohio corporate separation laws by failing to operate separately from unregulated affiliates. The complaint requests,
among other things, that any rates authorized by HB 6 or authorized by the PUCO in a proceeding over which the former
Chairman presided be made refundable; that the Ohio Companies be required to file a new distribution rate case at the earliest
possible date; and that the Ohio Companies’ corporate separation plans be modified to introduce institutional controls. The Ohio
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Companies are contesting the complaint. On December 21, 2021, the Citizens’ Utility Board of Ohio filed a notice of voluntary
dismissal of its complaint without prejudice. The PUCO dismissed the complaint without prejudice on January 12, 2022.
On November 1, 2021, the Ohio Companies, together with the OCC, PUCO Staff, and several other signatories, entered into an
Ohio Stipulation with the intent of resolving the ongoing energy efficiency rider audits, various SEET, proceedings, including the
Ohio Companies’ 2017 SEET proceeding, and the Ohio Companies’ quadrennial ESP review, each of which was pending before
the PUCO. Specifically, the Ohio Stipulation provides that the Ohio Companies’ current ESP IV passes the required statutory test
for their prospective SEET review as part of the Quadrennial Review of ESP IV, and except for limited circumstances, the
signatory parties have agreed not to challenge the Ohio Companies’ SEET return on equity calculation methodology for their
2021-2024 SEET proceedings. The Ohio Stipulation additionally affirms that: (i) the Ohio Companies’ ESP IV shall continue
through its previously authorized term of May 31, 2024; and (ii) the Ohio Companies will file their next base rate case in May
2024, and further, no signatory party will seek to adjust the Ohio Companies’ base distribution rates before that time, except in
limited circumstances. The Ohio Companies further agreed to refund $96 million to customers in connection with the 2017-2019
SEET cases, and to provide $210 million in future rate reductions for all customers, including $80 million in 2022, $60 million in
2023, $45 million in 2024, and $25 million in 2025. The PUCO approved the 2017-2019 SEET refunds and 2022 rate reductions
December 1, 2021, and refunds began in January 2022. As a result of the PUCO approval, FirstEnergy recognized a $96 million
pre-tax charge in the fourth quarter of 2021 at the regulated distribution segment within Amortization (deferral) of Regulatory
Assets, net, on the Consolidated Statements of Income associated with the refund. The future rate reductions will be recognized
as a reduction to regulated distribution segment’s revenue in the Consolidated Statements of Income as they are provided to the
Ohio Companies’ customers.
In connection with an ongoing annual audit of the Ohio Companies’ Rider DCR for 2020, and as a result of disclosures in
FirstEnergy’s Form 10-K for the year ended December 31, 2020 (filed on February 18, 2021), the PUCO expanded the scope of
the audit on March 10, 2021, to include a review of certain transactions that were either improperly classified, misallocated, or
lacked supporting documentation, and to determine whether funds collected from customers were used to pay the vendors, and
if so, whether or not the funds associated with those payments should be returned to customers through Rider DCR or through
an alternative proceeding. On August 3, 2021, the auditor filed its final report on this phase of the audit, and the parties submitted
comments and reply comments on this audit report in October 2021. Additionally, on September 29, 2021, the PUCO expanded
the scope of the audit in this proceeding to determine if the costs of the naming rights for FirstEnergy Stadium have been
recovered from the Ohio Companies’ customers. On November 19, 2021, the auditor filed its final report, in which the auditor
concluded that the FirstEnergy Stadium naming rights expenses were not recovered from Ohio customers. On December 15,
2021, the PUCO further expanded the scope of the audit to include an investigation into an apparent nondisclosure of a side
agreement in the Ohio Companies’ ESP IV settlement proceedings, but stayed its expansion of the audit until otherwise ordered
by the PUCO.
See “Outlook - Other Legal Proceedings” below for additional details on the government investigations and subsequent litigation
surrounding the investigation of HB 6.
PENNSYLVANIA
The Pennsylvania Companies operate under rates approved by the PPUC, effective as of January 27, 2017. On November 18,
2021, the PPUC issued orders to each of the Pennsylvania Companies directing they operate under DSPs for the June 1, 2019
through May 31, 2023 delivery period, which DSPs provide for the competitive procurement of generation supply for customers
who do not receive service from an alternative EGS. Under the 2019-2023 DSPs, supply will be provided by wholesale suppliers
through a mix of 3, 12 and 24-month energy contracts, as well as two RFPs for 2-year SREC contracts for ME, PN and Penn. On
December 14, 2021, the Pennsylvania Companies filed proposed DSPs for provision of generation for the June 1, 2023 through
May 31, 2027 delivery period, to be sourced through competitive procurements for customers who do not receive service from an
alternative EGS. Under the 2023-2027 DSPs, supply is proposed to be provided through a mix of 12 and 24-month energy
contracts, as well as long-term solar PPAs.
In March 2018, the PPUC approved adjusted customer rates of the Pennsylvania Companies to reflect the net impact of the Tax
Act. As a result, the Pennsylvania Companies established riders that, beginning July 1, 2018, refunded to customers tax savings
attributable to the Tax Act as compared to the amounts established in their most recent base rate proceedings on a current and
going forward basis. The amounts recorded as savings for the total period of January 1 through June 30, 2018, were tracked and
were to be addressed for treatment in a future proceeding. On May 17, 2021, the Pennsylvania Companies filed petitions with
the PPUC proposing to refund the net savings for the January through June 2018 period to customers beginning January 1,
2022. On November 18, 2021, the PPUC approved the Pennsylvania Companies' proposed refunds, but also revised a previous
methodology for calculating the net tax savings, which resulted in additional tax savings attributable to the Tax Act to be refunded
to customers and directed the Pennsylvania Companies to file new petitions to propose the timing and methodology to provide
these additional refunds to customers. The Pennsylvania Companies recalculated the net impact for 2018 through 2021 under
the revised PPUC methodology in comparison to amounts already refunded to customers under the existing riders, which
resulted in an additional $61 million in savings, with interest, to be provided to customers. As a result, FirstEnergy recognized a
pre-tax charge of $61 million in the fourth quarter of 2021 at the regulated distribution segment within Amortization (deferral) of
Regulatory Assets, net, on the Consolidated Statement of Income associated with the additional refund associated with the
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November 2021 PPUC order and methodology. The Pennsylvania Companies are required to file petitions to propose the timing
and methodology of the refund of these amounts by March 3, 2022.
Pursuant to Pennsylvania Act 129 of 2008 and PPUC orders, Pennsylvania EDCs implement energy efficiency and peak demand
reduction programs. The Pennsylvania Companies’ Phase III EE&C plans for the June 2016 through May 2021 period, which
were approved in March 2016, with expected costs up to $390 million, are designed to achieve the targets established in the
PPUC’s Phase III Final Implementation Order with full recovery through the reconcilable EE&C riders. On June 18, 2020, the
PPUC entered a Final Implementation Order for a Phase IV EE&C Plan, operating from June 2021 through May 2026. The Final
Implementation Order set demand reduction targets, relative to 2007 to 2008 peak demands, at 2.9% MW for ME, 3.3% MW for
PN, 2.0% MW for Penn, and 2.5% MW for WP; and energy consumption reduction targets, as a percentage of the Pennsylvania
Companies’ historic 2009 to 2010 reference load at 3.1% MWH for ME, 3.0% MWH for PN, 2.7% MWH for Penn, and 2.4%
MWH for WP. The Pennsylvania Companies’ Phase IV plans were filed November 30, 2020 and subsequently approved by
PPUC without modification on March 25, 2021.
Pennsylvania EDCs are permitted to seek PPUC approval of an LTIIP for infrastructure improvements and costs related to
highway relocation projects, after which a DSIC may be approved to recover LTIIP costs. On January 16, 2020, the PPUC
approved the Pennsylvania Companies’ LTIIPs for the five-year period beginning January 1, 2020 and ending December 31,
2024 for a total capital investment of approximately $572 million for certain infrastructure improvement initiatives. On June 25,
2021, the Pennsylvania OCA filed a complaint against Penn’s quarterly DSIC rate, disputing the recoverability of the Companies’
automated distribution management system investment under the DSIC mechanism. On January 26, 2022, the parties filed a
joint petition for settlement that resolves all issues in this matter pending PPUC approval.
Following the Pennsylvania Companies’ 2016 base rate proceedings, the PPUC ruled in a separate proceeding related to the
DSIC mechanisms that the Pennsylvania Companies were not required to reflect federal and state income tax deductions related
to DSIC-eligible property in DSIC rates. The decision was appealed to the Pennsylvania Supreme Court and in July 2021 the
court upheld the Pennsylvania Commonwealth Court’s reversal of the PPUC’s decision and remanded the matter back to the
PPUC for determination as to how DSIC calculations shall account for ADIT and state taxes. The matter awaits further action by
the PPUC. The adverse ruling by the Pennsylvania Supreme Court is not expected to result in a material impact to FirstEnergy.
The PPUC issued an order on March 13, 2020, forbidding utilities from terminating service for non-payment for the duration of
the COVID-19 pandemic. On May 13, 2020, the PPUC issued a Secretarial letter directing utilities to track all prudently incurred
incremental costs arising from the COVID-19 pandemic, and to create a regulatory asset for future recovery of incremental
uncollectibles incurred as a result of the COVID-19 pandemic and termination moratorium. On October 13, 2020, the PPUC
entered an order lifting the service termination moratorium effective November 9, 2020, subject to certain additional notification,
payment procedures and exceptions, and permits the Pennsylvania Companies to create a regulatory asset for all incremental
expenses associated with their compliance with the order. On March 19, 2021, the PPUC entered an order lifting the moratorium
in total effective March 31, 2021, subject to certain additional guidelines regarding the duration of payment arrangements and
reporting obligations.
WEST VIRGINIA
MP and PE provide electric service to all customers through traditional cost-based, regulated utility ratemaking and operate
under WVPSC approved rates that became effective in February 2015. MP and PE recover net power supply costs, including
fuel costs, purchased power costs and related expenses, net of related market sales revenue through the ENEC. MP’s and PE’s
ENEC rate is updated annually.
On December 30, 2020, MP and PE filed with the WVPSC a determination of the rate impact of the Tax Act with respect to ADIT.
The filing proposed an annual revenue reduction of $2.6 million, effective January 1, 2022, with reconciliation and any resulting
adjustments incorporated into annual ENEC proceedings. On August 12, 2021, a unanimous settlement was reached with all the
parties agreeing to a $7.7 million rate reduction beginning January 1, 2022, with a true-up in the ENEC proceeding each year. On
November 30, 2021, the WVPSC approved the settlement on all terms, except for the proposed effective date of the rate
reduction, which was held in abeyance until further notice.
On August 27, 2021, MP and PE filed with the WVPSC their annual ENEC case requesting an increase in ENEC rates of $19.6
million beginning January 1, 2022, which represented a 1.5% increase to the rates currently in effect. WVPSC issued an order on
December 29, 2021, granting the requested $19.6 million increase in ENEC rates. Among other things, the order requires MP
and PE to refund to its large industrial customers their respective portion of the $7.7 million rate reduction discussed above and
also requires MP and PE to negotiate a PPA for its capacity shortfall and a reasonable reserve margin if certain conditions are
met.
On November 22, 2021, MP and PE filed with the WVPSC their plan to construct 50 MWs of solar generation at five sites in West
Virginia. The plan includes a tariff to offer solar power to West Virginia customers and cost recovery for MP and PE from other
customers through a surcharge for any solar investment not fully subscribed by their customers. A hearing has been set for
March 16, 2022. The solar generation project is expected to cost approximately $100 million and begin being in-service by the
end of 2023 and finalized no later than the end of 2025.
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On August 27, 2021, MP and PE filed with the WVPSC a biennial review of the vegetation management surcharge seeking a $16
million annual revenue increase. A settlement among the parties was reached on December 3, 2021 and on December 27, 2021,
the WVPSC approved the settlement, which granted a $16 million increase in rates, and continued the vegetation management
program and surcharge for another two years. Additionally, the WVPSC order added a provision requiring equipment inspections
be performed within a reasonable time after vegetation management occurs on a circuit.
On December 17, 2021, MP and PE filed with the WVPSC for approval of environmental compliance projects at the Ft. Martin
and Harrison Power Stations to comply with the EPA’s ELG and operate these plants beyond 2028. The request includes a
surcharge to recover the expected $142 million capital investment and $3 million in annual operation and maintenance expense.
A ruling from the WVPSC is expected in mid-summer 2022, and if approved, construction would be expected to be completed by
the end of 2025. See "Environmental Matters - Clean Water Act" below, for additional details on the EPA's ELG.
FERC REGULATORY MATTERS
Under the FPA, FERC regulates rates for interstate wholesale sales, transmission of electric power, accounting and other
matters, including construction and operation of hydroelectric projects. With respect to their wholesale services and rates, the
Utilities, AE Supply and the Transmission Companies are subject to regulation by FERC. FERC regulations require JCP&L, MP,
PE, WP and the Transmission Companies to provide open access transmission service at FERC-approved rates, terms and
conditions. Transmission facilities of JCP&L, MP, PE, WP and the Transmission Companies are subject to functional control by
PJM and transmission service using their transmission facilities is provided by PJM under the PJM Tariff.
The following table summarizes the key terms of rate orders in effect for transmission customer billings for FirstEnergy's
transmission owner entities as of December 31, 2021:
Company
ATSI
JCP&L
MP
PE
WP
MAIT
TrAIL
Rates Effective
Capital Structure
Allowed ROE
January 1, 2015
Actual (13-month average)
January 1, 2020
January 1, 2021(1)(2)
January 1, 2021(1)(2)
January 1, 2021(1)(2)
July 1, 2017
Actual (13-month average)
Actual (13-month average)(1)
Actual (13-month average)(1)
Actual (13-month average)(1)
Lower of Actual (13-month
average) or 60%
10.38%
10.20%
11.35%(1)
11.35%(1)
11.35%(1)
10.3%
July 1, 2008
Actual (year-end)
12.7%(TrAIL the Line & Black Oak SVC)
11.7% (All other projects)
(1) Effective on January 1, 2021, MP, PE, and WP have implemented a forward-looking formula rate, which has been accepted
by FERC, subject to refund, pending further hearing and settlement procedures.
(2) See FERC Action on Tax Act below.
FERC regulates the sale of power for resale in interstate commerce in part by granting authority to public utilities to sell
wholesale power at market-based rates upon showing that the seller cannot exert market power in generation or transmission or
erect barriers to entry into markets. The Utilities and AE Supply each have been authorized by FERC to sell wholesale power in
interstate commerce at market-based rates and have a market-based rate tariff on file with FERC, although in the case of the
Utilities major wholesale purchases remain subject to review and regulation by the relevant state commissions.
Federally enforceable mandatory reliability standards apply to the bulk electric system and impose certain operating, record-
keeping and reporting requirements on the Utilities, AE Supply, and the Transmission Companies. NERC is the ERO designated
by FERC to establish and enforce these reliability standards, although NERC has delegated day-to-day implementation and
enforcement of these reliability standards to six regional entities, including RFC. All of the facilities that FirstEnergy operates are
located within RFC. FirstEnergy actively participates in the NERC and RFC stakeholder processes, and otherwise monitors and
manages its companies in response to the ongoing development, implementation and enforcement of the reliability standards
implemented and enforced by RFC.
FirstEnergy believes that it is in material compliance with all currently effective and enforceable reliability standards.
Nevertheless, in the course of operating its extensive electric utility systems and facilities, FirstEnergy occasionally learns of
isolated facts or circumstances that could be interpreted as excursions from the reliability standards. If and when such
occurrences are found, FirstEnergy develops information about the occurrence and develops a remedial response to the specific
circumstances, including in appropriate cases “self-reporting” an occurrence to RFC. Moreover, it is clear that NERC, RFC and
FERC will continue to refine existing reliability standards as well as to develop and adopt new reliability standards. Any inability
on FirstEnergy’s part to comply with the reliability standards for its bulk electric system could result in the imposition of financial
penalties, or obligations to upgrade or build transmission facilities, that could have a material adverse effect on its financial
condition, results of operations and cash flows.
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FERC Audit
FERC’s Division of Audits and Accounting initiated a nonpublic audit of FESC in February 2019. Among other matters, the audit
is evaluating FirstEnergy’s compliance with certain accounting and reporting requirements under various FERC regulations. On
February 4, 2022, FERC filed the final audit report for the period of January 1, 2015 through September 30, 2021, which included
several findings and recommendations. One of the audit report findings and related recommendations state that FirstEnergy may
have used an inappropriate methodology for allocation of certain costs to regulatory capital accounts under certain FERC
regulations and reporting. Based on the finding and related recommendations, FirstEnergy is currently performing an analysis of
these costs and how it impacted certain wholesale transmission customer rates. FirstEnergy is unable to predict or estimate the
final outcome of this analysis and audit, however, it could result in refunds, with interest, to certain wholesale transmission
customers and/or write-offs of previously capitalized costs if they are determined to be nonrecoverable.
ATSI Transmission Formula Rate
On May 1, 2020, ATSI filed amendments to its formula rate to recover regulatory assets for certain costs that ATSI incurred as a
result of its 2011 move from MISO to PJM, certain costs allocated to ATSI by FERC for transmission projects that were
constructed by other MISO transmission owners, and certain costs for transmission-related vegetation management programs. A
portion of these costs would have been charged to the Ohio Companies. Additionally, ATSI proposed certain income tax-related
adjustments and certain tariff changes addressing the revenue credit components of the formula rate template. On June 30,
2020, FERC issued an initial order accepting the tariff amendments subject to refund and setting the matter for hearing and
settlement proceedings. ATSI and the parties to the FERC proceeding subsequently were able to reach settlement, and on
October 14, 2021, filed the settlement with FERC. As a result of the filed settlement, FirstEnergy recognized a $21 million pre-tax
charge during the third quarter of 2021, which was recognized in Other Operating Expenses on the FirstEnergy Consolidated
Statements of Income. This $21 million charge reflects the difference between amounts originally recorded as regulatory assets
and amounts which will ultimately be recovered as a result of the pending settlement. From a segment perspective, during the
third quarter of 2021, the Regulated Transmission segment recorded a pre-tax charge of $48 million and the Regulated
Distribution segment recognized a $27 million reduction to a reserve previously recorded in 2010. In addition, the settlement
provides for partial recovery of future incurred costs allocated to ATSI by MISO for the above-referenced transmission projects
that were constructed by other MISO transmission owners, which is not expected to have a material impact on FirstEnergy or
ATSI. The uncontested settlement is pending before FERC for approval.
FERC Actions on Tax Act
On March 15, 2018, FERC initiated proceedings on the question of how to address possible changes to ADIT and bonus
depreciation as a result of the Tax Act. Such possible changes could impact FERC-jurisdictional rates, including transmission
rates. On November 21, 2019, FERC issued a final rule (Order No. 864). Order No. 864 requires utilities with transmission
formula rates to update their formula rate templates to include mechanisms to: (i) deduct any excess ADIT from or add any
deficient ADIT to their rate base; (ii) raise or lower their income tax allowances by any amortized excess or deficient ADIT; and
(iii) incorporate a new permanent worksheet into their rates that will annually track information related to excess or deficient ADIT.
Per FERC directives, ATSI submitted its compliance filing on May 1, 2020. MAIT submitted its compliance filing on June 1, 2020.
On November 18, 2021, FERC issued an order that: (i) accepted ATSI proposed tariff amendments to its rate base adjustment
mechanism, effective January 27, 2020; (ii) directed ATSI to make a further compliance filing by January 17, 2022; and (iii) set
the amount of ATSI’s recorded ADIT balances as of December 31, 2017, for hearing and settlement procedures. ATSI submitted
the compliance filing, and is participating in settlement negotiations. On December 3, 2021, FERC issued an order that (i)
accepted MAIT’s proposed tariff amendments to its rate base adjustment mechanism, effective January 27, 2020; (ii) directed
MAIT to make a further compliance filing by February 1, 2022; and (iii) set the amount of MAIT’s recorded ADIT balances as of
December 31, 2017 for hearing and settlement procedures. MAIT submitted the compliance filing, and is participating in
settlement negotiations. On May 15, 2020, TrAIL submitted its compliance filing and on June 1, 2020, PATH submitted its
required compliance filing. On May 4, 2021, FERC staff requested additional information about PATH’s proposed rate base
adjustment mechanism, and PATH submitted the requested information on June 3, 2021. On July 12, 2021, FERC staff
requested additional information about TrAIL’s proposed rate base adjustment mechanism. TrAIL filed its response on August 6,
2021. The PATH and TrAIL compliance filings each remain pending before FERC. MP, WP and PE (as holders of a “stated”
transmission rate when Order No. 864 issued) are addressing these requirements in the transmission formula rates amendments
that were filed on October 29, 2020, and which have been accepted by FERC effective January 1, 2021, subject to refund,
pending further hearing and settlement procedures, MP, WP and PE are engaged in settlement negotiations with other parties to
this proceeding. JCP&L addressed these requirements as part of its transmission formula rate case, which was resolved by a
settlement approved by FERC on April 15, 2021.
Transmission ROE Methodology
On May 20, 2021, in a case not involving FirstEnergy, FERC issued Opinion No. 575 in which it reiterated the nationwide ROE
methodology set forth in 2020 in Opinion Nos. 569-A and 569-B. Under this methodology, FERC employs three financial models
– discounted cash flow, capital-asset pricing, and risk premium – to calculate a composite zone of reasonableness. As it has
done in other recent ROE cases, FERC rejected the use of the expected earnings methodology in calculating the authorized
ROE. A request for clarification or, alternatively, rehearing of Opinion No. 575 was filed on June 21, 2021, and on September 9,
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2021, FERC issued an order clarifying aspects of its prior opinion, but affirming the result. On July 15, 2021, FERC issued
another order, addressing ROE for a generation company in New England, which applied a standard consistent with Opinion
Nos. 569-A and 569-B. FERC’s Opinion Nos. 569-A and 569-B, upon which Opinion No. 575 is based, have been appealed to
the D.C. Circuit. FirstEnergy is not participating in the appeal. Any changes to FERC’s transmission rate ROE and incentive
policies for transmission rates would be applied on a prospective basis.
On March 20, 2020, FERC initiated a rulemaking proceeding on the transmission rate incentives provisions of Section 219 of the
2005 Energy Policy Act. FirstEnergy submitted comments through EEI and as part of a consortium of PJM Transmission Owners.
In a supplemental rulemaking proceeding that was initiated on April 15, 2021, FERC requested comments on, among other
things, whether to require utilities that have been members of an RTO for three years or more and that have been collecting an
“RTO membership” ROE incentive adder to file tariff updates that would terminate collection of the incentive adder. Initial
comments on the proposed rule were filed on June 25, 2021, and reply comments were filed on July 26, 2021. The rulemaking
remains pending before FERC. FirstEnergy is a member of PJM and its transmission subsidiaries could be affected by the
supplemental proposed rule. FirstEnergy participated in comments that were submitted by a group of PJM transmission owners
and by various industry trade groups. If there were to be any changes to FirstEnergy transmission incentive ROE, such changes
will be applied on a prospective basis.
JCP&L Transmission Formula Rate
On October 30, 2019, JCP&L filed tariff amendments with FERC to convert JCP&L’s existing stated transmission rate to a
forward-looking formula transmission rate. JCP&L requested that the tariff amendments become effective January 1, 2020. On
December 19, 2019, FERC issued its initial order in the case, allowing JCP&L to transition to a forward-looking formula rate as of
January 1, 2020 as requested, subject to refund, pending further hearing and settlement proceedings. JCP&L and the parties to
the FERC proceeding subsequently were able to reach settlement, and on February 2, 2021, JCP&L filed an offer of settlement
with FERC. On April 15, 2021, FERC approved the settlement agreement as filed, with no changes, effective January 1, 2021.
Allegheny Power Zone Transmission Formula Rate Filings
On October 29, 2020, MP, PE and WP filed tariff amendments with FERC to implement a forward-looking formula transmission
rate, to be effective January 1, 2021. In addition, on October 30, 2020, KATCo filed a proposed new tariff to establish a forward-
looking formula rate and requested that the new rate become effective January 1, 2021. In its filing, KATCo explained that while it
currently owns no transmission assets, it may build new transmission facilities in the Allegheny zone, and that it may seek
required state and federal authorizations to acquire transmission assets from PE and WP by January 1, 2022. These
transmission rate filings were accepted for filing by FERC on December 31, 2020, effective January 1, 2021, subject to refund,
pending further hearing and settlement procedures and were consolidated into a single proceeding. MP, PE and WP, and KATCo
are engaged in settlement negotiations with the other parties to the formula rate proceedings. KATCo will be included in the
Regulated Transmission reportable segment.
ENVIRONMENTAL MATTERS
Various federal, state and local authorities regulate FirstEnergy with regard to air and water quality, hazardous and solid waste
disposal, and other environmental matters. While FirstEnergy’s environmental policies and procedures are designed to achieve
compliance with applicable environmental laws and regulations, such laws and regulations are subject to periodic review and
potential revision by the implementing agencies. FirstEnergy cannot predict the timing or ultimate outcome of any of these
reviews or how any future actions taken as a result thereof may materially impact its business, results of operations, cash flows
and financial condition.
Clean Air Act
FirstEnergy complies with SO2 and NOx emission reduction requirements under the CAA and SIP(s) by burning lower-sulfur fuel,
utilizing combustion controls and post-combustion controls and/or using emission allowances.
CSAPR requires reductions of NOx and SO2 emissions in two phases (2015 and 2017), ultimately capping SO2 emissions in
affected states to 2.4 million tons annually and NOx emissions to 1.2 million tons annually. CSAPR allows trading of NOx and
SO2 emission allowances between power plants located in the same state and interstate trading of NOx and SO2 emission
allowances with some restrictions. On July 28, 2015, the D.C. Circuit ordered the EPA to reconsider the CSAPR caps on NOx
and SO2 emissions from power plants in 13 states, including West Virginia. This followed the 2014 U.S. Supreme Court ruling
generally upholding the EPA’s regulatory approach under CSAPR but questioning whether the EPA required upwind states to
reduce emissions by more than their contribution to air pollution in downwind states. The EPA issued a CSAPR Update on
September 7, 2016, reducing summertime NOx emissions from power plants in 22 states in the eastern U.S., including West
Virginia, beginning in 2017. Various states and other stakeholders appealed the CSAPR Update to the D.C. Circuit in November
and December 2016. On September 13, 2019, the D.C. Circuit remanded the CSAPR Update to the EPA citing that the rule did
not eliminate upwind states’ significant contributions to downwind states’ air quality attainment requirements within applicable
attainment deadlines.
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Also, during this time, in March 2018, the State of New York filed a CAA Section 126 petition with the EPA alleging that NOx
emissions from nine states (including West Virginia) significantly contribute to New York’s inability to attain the ozone NAAQS.
The petition sought suitable emission rate limits for large stationary sources that are allegedly affecting New York’s air quality
within the three years allowed by CAA Section 126. On September 20, 2019, the EPA denied New York’s CAA Section 126
petition. On October 29, 2019, the State of New York appealed the denial of its petition to the D.C. Circuit. On July 14, 2020, the
D.C. Circuit reversed and remanded the New York petition to the EPA for further consideration. On March 15, 2021, the EPA
issued a revised CSAPR Update that addresses, among other things, the remands of the CSAPR Update and the New York
Section 126 Petition. Depending on the outcome of any appeals and how the EPA and the states ultimately implement the
revised CSAPR Update, the future cost of compliance may materially impact FirstEnergy's operations, cash flows and financial
condition.
In February 2019, the EPA announced its final decision to retain without changes the NAAQS for SO2, specifically retaining the
2010 primary (health-based) 1-hour standard of 75 PPB. As of March 31, 2020, FirstEnergy has no power plants operating in
areas designated as non-attainment by the EPA.
Climate Change
There are several initiatives to reduce GHG emissions at the state, federal and international level. Certain northeastern states
are participating in the RGGI and western states led by California, have implemented programs, primarily cap and trade
mechanisms, to control emissions of certain GHGs. Additional policies reducing GHG emissions, such as demand reduction
programs, renewable portfolio standards and renewable subsidies have been implemented across the nation.
In September 2016, the U.S. joined in adopting the agreement reached on December 12, 2015, at the United Nations Framework
Convention on Climate Change meetings in Paris to reduce GHGs. The Paris Agreement’s non-binding obligations to limit global
warming to below two degrees Celsius became effective on November 4, 2016. On June 1, 2017, the Trump Administration
announced that the U.S. would cease all participation in the Paris Agreement. On January 20, 2021, President Biden signed an
executive order re-adopting the agreement on behalf of the U.S. In November 2020, FirstEnergy published its Climate Story
which includes its climate position and strategy, as well as a new comprehensive and ambitious GHG emission goal. FirstEnergy
pledged to achieve carbon neutrality by 2050 and set an interim goal for a 30% reduction in GHGs within FirstEnergy’s direct
operational control by 2030, based on 2019 levels. Future resource plans to achieve carbon reductions, including any
determination of retirement dates of the regulated coal-fired generation, will be developed by working collaboratively with
regulators in West Virginia. Determination of the useful life of the regulated coal-fired generation could result in changes in
depreciation, and/or continued collection of net plant in rates after retirement, securitization, sale, impairment, or regulatory
disallowances. If MP is unable to recover these costs, it could have a material adverse effect on FirstEnergy’s and/or MP’s
financial condition, results of operations, and cash flow. Furthermore, FirstEnergy cannot currently estimate the financial impact
of climate change policies, although potential legislative or regulatory programs restricting CO2 emissions, or litigation alleging
damages from GHG emissions, could require material capital and other expenditures or result in changes to its operations.
In December 2009, the EPA released its final “Endangerment and Cause or Contribute Findings for GHGs under the Clean Air
Act,” concluding that concentrations of several key GHGs constitute an "endangerment" and may be regulated as "air pollutants"
under the CAA and mandated measurement and reporting of GHG emissions from certain sources, including electric generating
plants. Subsequently, the EPA released its final CPP regulations in August 2015 to reduce CO2 emissions from existing fossil
fuel-fired EGUs and finalized separate regulations imposing CO2 emission limits for new, modified, and reconstructed fossil fuel-
fired EGUs. Numerous states and private parties filed appeals and motions to stay the CPP with the D.C. Circuit in October
2015. On February 9, 2016, the U.S. Supreme Court stayed the rule during the pendency of the challenges to the D.C. Circuit
and U.S. Supreme Court. On March 28, 2017, an executive order, entitled “Promoting Energy Independence and Economic
Growth,” instructed the EPA to review the CPP and related rules addressing GHG emissions and suspend, revise or rescind the
rules if appropriate. On June 19, 2019, the EPA repealed the CPP and replaced it with the ACE rule that established guidelines
for states to develop standards of performance to address GHG emissions from existing coal-fired generation. On January 19,
2021, the D.C. Circuit vacated and remanded the ACE rule declaring that the EPA was “arbitrary and capricious” in its rule
making and, as such, the ACE rule is no longer in effect and all actions thus far taken by states to implement the federally
mandated rule are now null and void. The D.C. Circuit decision is subject to legal challenge. Depending on the outcomes of
further appeals and how any final rules are ultimately implemented, the future cost of compliance may be material.
Clean Water Act
Various water quality regulations, the majority of which are the result of the federal CWA and its amendments, apply to
FirstEnergy’s facilities. In addition, the states in which FirstEnergy operates have water quality standards applicable to
FirstEnergy’s operations.
On September 30, 2015, the EPA finalized new, more stringent effluent limits for the Steam Electric Power Generating category
(40 CFR Part 423) for arsenic, mercury, selenium and nitrogen for wastewater from wet scrubber systems and zero discharge of
pollutants in ash transport water. The treatment obligations were to phase-in as permits are renewed on a five-year cycle from
2018 to 2023. However, on April 13, 2017, the EPA granted a Petition for Reconsideration and on September 18, 2017, the EPA
postponed certain compliance deadlines for two years. On August 31, 2020, the EPA issued a final rule revising the effluent limits
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for discharges from wet scrubber systems, retaining the zero-discharge standard for ash transport water, (with some limited
discharge allowances), and extending the deadline for compliance to December 31, 2025 for both. In addition, the EPA allows for
less stringent limits for sub-categories of generating units based on capacity utilization, flow volume from the scrubber system,
and unit retirement date. The EPA is reconsidering the ELG rule with a publicly announced target of issuing a proposed revised
rule in the Fall of 2022 and a final rule by the Spring of 2023. In the interim, the rule issued on August 31, 2020, remains in effect.
Depending on the outcome of appeals and how final rules are ultimately implemented, the compliance with these standards,
could require additional capital expenditures or changes in operations at Ft. Martin and Harrison power stations from what was
filed with the WVPSC in December 2021 that seeks approval of environmental compliance projects to comply with the EPA’s
ELG.
After the completion of a negotiated settlement, a complaint was filed by the EPA and PA DEP on January 10, 2022 in Federal
District Court for the Western District of Pennsylvania, alleging, among other things, that WP violated the CWA in connection with
past boron exceedances at WP’s Springdale and Mingo landfills. On January 11, 2022, WP entered into a consent decree with
the EPA and PA DEP resolving the matters addressed in the complaint, which, among other things, requires a civil penalty of
$610 thousand. The consent decree is subject to final approval by the District Court pending public comment.
Regulation of Waste Disposal
Federal and state hazardous waste regulations have been promulgated as a result of the RCRA, as amended, and the Toxic
Substances Control Act. Certain CCRs, such as coal ash, were exempted from hazardous waste disposal requirements pending
the EPA’s evaluation of the need for future regulation.
In April 2015, the EPA finalized regulations for the disposal of CCRs (non-hazardous), establishing national standards for landfill
design, structural integrity design and assessment criteria for surface impoundments, groundwater monitoring and protection
procedures and other operational and reporting procedures to assure the safe disposal of CCRs from electric generating plants.
On September 13, 2017, the EPA announced that it would reconsider certain provisions of the final regulations. On July 29,
2020, the EPA published a final rule again revising the date that certain CCR impoundments must cease accepting waste and
initiate closure to April 11, 2021. The final rule also allows for an extension of the closure deadline based on meeting proscribed
site-specific criteria. On November 30, 2020, AE Supply submitted a closure deadline extension request to the EPA seeking to
extend the closure date of McElroy's Run CCR impoundment facility until 2024, which request is pending technical review by the
EPA. AE Supply continues to operate McElroy’s Run as a disposal facility for FG’s Pleasants Power Station.
FE or its subsidiaries have been named as potentially responsible parties at waste disposal sites, which may require cleanup
under the CERCLA. Allegations of disposal of hazardous substances at historical sites and the liability involved are often
unsubstantiated and subject to dispute; however, federal law provides that all potentially responsible parties for a particular site
may be liable on a joint and several basis. Environmental liabilities that are considered probable have been recognized on the
Consolidated Balance Sheets as of December 31, 2021, based on estimates of the total costs of cleanup, FirstEnergy’s
proportionate responsibility for such costs and the financial ability of other unaffiliated entities to pay. Total liabilities of
approximately $105 million have been accrued through December 31, 2021, of which, approximately $70 million are for
environmental remediation of former MGP and gas holder facilities in New Jersey, which are being recovered by JCP&L through
a non-bypassable SBC. FE or its subsidiaries could be found potentially responsible for additional amounts or additional sites,
but the loss or range of losses cannot be determined or reasonably estimated at this time.
OTHER LEGAL PROCEEDINGS
United States v. Larry Householder, et al.
On July 21, 2020, a complaint and supporting affidavit containing federal criminal allegations were unsealed against the now
former Ohio House Speaker Larry Householder and other individuals and entities allegedly affiliated with Mr. Householder. Also,
on July 21, 2020, and in connection with the investigation, FirstEnergy received subpoenas for records from the U.S. Attorney’s
Office for the S.D. Ohio. FirstEnergy was not aware of the criminal allegations, affidavit or subpoenas before July 21, 2020.
On July 21, 2021, FE entered into a three-year DPA with the U.S. Attorney’s Office that, subject to court proceedings, resolves
this matter. Under the DPA, FE has agreed to the filing of a criminal information charging FE with one count of conspiracy to
commit honest services wire fraud. The DPA requires that FirstEnergy, among other obligations: (i) continue to cooperate with the
U.S. Attorney’s Office in all matters relating to the conduct described in the DPA and other conduct under investigation by the
U.S. government; (ii) pay a criminal monetary penalty totaling $230 million within sixty days, which shall consist of (x) $115
million paid by FE to the United States Treasury and (y) $115 million paid by FE to the ODSA to fund certain assistance
programs, as determined by the ODSA, for the benefit of low-income Ohio electric utility customers; (iii) publish a list of all
payments made in 2021 to either 501(c)(4) entities or to entities known by FirstEnergy to be operating for the benefit of a public
official, either directly or indirectly, and update the same on a quarterly basis during the term of the DPA; (iv) issue a public
statement, as dictated in the DPA, regarding FE’s use of 501(c)(4) entities; and (v) continue to implement and review its
compliance and ethics program, internal controls, policies and procedures designed, implemented and enforced to prevent and
detect violations of the U.S. laws throughout its operations, and to take certain related remedial measures. The $230 million
payment will neither be recovered in rates or charged to FirstEnergy customers nor will FirstEnergy seek any tax deduction
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related to such payment. The entire amount of the monetary penalty was recognized as expense in the second quarter of 2021,
and paid in the third quarter of 2021. Under the terms of the DPA, the criminal information will be dismissed after FirstEnergy fully
complies with its obligations under the DPA.
Legal Proceedings Relating to United States v. Larry Householder, et al.
On August 10, 2020, the SEC, through its Division of Enforcement, issued an order directing an investigation of possible
securities laws violations by FE, and on September 1, 2020, issued subpoenas to FE and certain FE officers. On April 28, 2021,
the SEC issued an additional subpoena to FE. While no contingency has been reflected in its consolidated financial statements,
FE believes that it is probable that it will incur a loss in connection with the resolution of the SEC investigation. Given the ongoing
nature and complexity of the review, inquiries and investigations, FE cannot yet reasonably estimate a loss or range of loss that
may arise from the resolution of the SEC investigation.
In addition to the subpoenas referenced above under “—United States v. Larry Householder, et. al.” and the SEC investigation,
certain FE stockholders and FirstEnergy customers filed several lawsuits against FirstEnergy and certain current and former
directors, officers and other employees, and the complaints in each of these suits is related to allegations in the complaint and
supporting affidavit relating to HB 6 and the now former Ohio House Speaker Larry Householder and other individuals and
entities allegedly affiliated with Mr. Householder. The plaintiffs in each of the below cases seek, among other things, to recover
an unspecified amount of damages (unless otherwise noted). Unless otherwise indicated, no contingency has been reflected in
FirstEnergy’s consolidated financial statements with respect to these lawsuits as a loss is neither probable, nor is a loss or range
of a loss reasonably estimable.
•
In re FirstEnergy Corp. Securities Litigation (Federal District Court, S.D. Ohio); on July 28, 2020 and August 21, 2020,
purported stockholders of FE filed putative class action lawsuits alleging violations of the federal securities laws. Those
actions have been consolidated and a lead plaintiff, the Los Angeles County Employees Retirement Association, has
been appointed by the court. A consolidated complaint was filed on February 26, 2021. The consolidated complaint
alleges, on behalf of a proposed class of persons who purchased FE securities between February 21, 2017 and July 21,
2020, that FE and certain current or former FE officers violated Sections 10(b) and 20(a) of the Exchange Act by issuing
misrepresentations or omissions concerning FE’s business and results of operations. The consolidated complaint also
alleges that FE, certain current or former FE officers and directors, and a group of underwriters violated Sections 11,
12(a)(2) and 15 of the Securities Act of 1933 as a result of alleged misrepresentations or omissions in connection with
offerings of senior notes by FE in February and June 2020. FE believes that it is probable that it will incur a loss in
connection with the resolution of this lawsuit. Given the ongoing nature and complexity of such litigation, FE cannot yet
reasonably estimate a loss or range of loss.
•
• MFS Series Trust I, et al. v. FirstEnergy Corp., et al. (Federal District Court, S.D. Ohio) on December 17, 2021,
purported stockholders of FE filed a complaint against FE, certain current and former officers, and certain current and
former officers of EH. The complaint alleges that the defendants violated Sections 10(b) and 20(a) of the Exchange Act
by issuing alleged misrepresentations or omissions regarding FE’s business and its results of operations, and seeks the
same relief as the In re FirstEnergy Corp. Securities Litigation described above. FE believes that it is probable that it will
incur a loss in connection with the resolution of this lawsuit. Given the ongoing nature and complexity of such litigation,
FE cannot yet reasonably estimate a loss or range of loss.
State of Ohio ex rel. Dave Yost, Ohio Attorney General v. FirstEnergy Corp., et al. and City of Cincinnati and City of
Columbus v. FirstEnergy Corp. (Common Pleas Court, Franklin County, OH, all actions have been consolidated); on
September 23, 2020 and October 27, 2020, the OAG and the cities of Cincinnati and Columbus, respectively, filed
complaints against several parties including FE (the OAG also named FES as a defendant), each alleging civil
violations of the Ohio Corrupt Activity Act in connection with the passage of HB 6. On January 13, 2021, the OAG filed a
motion for a temporary restraining order and preliminary injunction against FirstEnergy seeking to enjoin FirstEnergy
from collecting the Ohio Companies' decoupling rider. On January 31, 2021, FE reached a partial settlement with the
OAG and the cities of Cincinnati and Columbus with respect to the temporary restraining order and preliminary
injunction request and related issues. In connection with the partial settlement, the Ohio Companies filed an application
on February 1, 2021, with the PUCO to set their respective decoupling riders (CSR) to zero. On February 2, 2021, the
PUCO approved the application of the Ohio Companies setting the rider to zero and no additional customer bills will
include new decoupling rider charges after February 8, 2021. The cases are stayed pending final resolution of the
United States v. Larry Householder, et al. criminal proceeding described above, although on August 13, 2021, new
defendants were added to the complaint, including two former officers of FirstEnergy. On November 9, 2021, the OAG
filed a motion to lift the agreed-upon stay, which FE opposed on November 19, 2021; the motion remains pending. On
December 2, 2021, the cities and FE entered a stipulated dismissal with prejudice of the cities’ suit.
Smith v. FirstEnergy Corp. et al., Buldas v. FirstEnergy Corp. et al., and Hudock and Cameo Countertops, Inc. v.
FirstEnergy Corp. et al. (Federal District Court, S.D. Ohio, all actions have been consolidated); on July 27, 2020, July
31, 2020, and August 5, 2020, respectively, purported customers of FE filed putative class action lawsuits against FE
and FESC, as well as certain current and former FE officers, alleging civil Racketeer Influenced and Corrupt
Organizations Act violations and related state law claims. The court denied FE’s motions to dismiss and stay discovery
on February 10 and 11, 2021, respectively, and the defendants submitted answers to the complaint on March 10, 2021.
The plaintiffs moved to certify the case as a class action on June 28, 2021, and moved for leave to amend the complaint
to add FES as a defendant on September 27, 2021. The court granted the motion to amend on November 10, 2021. On
•
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November 9, 2021, the court issued an order granting Plaintiffs' motion for class certification, but vacated that order on
November 19, 2021, to allow defendants to take the named plaintiffs’ depositions and to file an opposition to the motion,
which they filed on December 14, 2021. On November 19, 2021, FE and FESC moved for judgment on the pleadings.
One of the individual defendants moved to dismiss the amended complaint on November 24, 2021. On December 28,
2021, the parties jointly moved the court to stay consideration of the pending motions for class certification, to dismiss,
and for judgment on the pleadings for 45 days. The court granted the motion on December 29, 2021, and the cases are
currently stayed. FE is engaged with the parties in settlement discussions, and believes that it is probable that it will
incur a loss in connection with the resolution of these lawsuits. As a result, FirstEnergy recognized in the fourth quarter
of 2021 a pre-tax reserve of $37.5 million in the aggregate with respect to these lawsuits and the Emmons lawsuit
below.
Emmons v. FirstEnergy Corp. et al. (Common Pleas Court, Cuyahoga County, OH); on August 4, 2020, a purported
customer of FirstEnergy filed a putative class action lawsuit against FE, FESC, the Ohio Companies, along with FES,
alleging several causes of action, including negligence and/or gross negligence, breach of contract, unjust enrichment,
and unfair or deceptive consumer acts or practices. On October 1, 2020, plaintiffs filed a First Amended Complaint,
adding as a plaintiff a purported customer of FirstEnergy and alleging a civil violation of the Ohio Corrupt Activity Act
and civil conspiracy against FE, FESC and FES. On May 4, 2021, the court granted the defendants’ motion to dismiss
plaintiffs’ breach of contract claims and denied the remainder of the motions to dismiss. The defendants submitted
answers to the complaint on June 1, 2021. Discovery is proceeding. On December 30, 2021, the plaintiff filed a Second
Amended Complaint removing one of the named plaintiffs and updating the class definition. FE is engaged with the
parties in settlement discussions, and believes that it is probable that it will incur a loss in connection with the resolution
of these lawsuits. As a result, FirstEnergy recognized in the fourth quarter of 2021 a pre-tax reserve of $37.5 million in
the aggregate with respect to this lawsuit and the lawsuits above consolidated with Smith in the S.D. Ohio alleging,
among other things, civil violations of the Racketeer Influenced and Corrupt Organizations Act.
On February 9, 2022, FE, acting through the SLC, agreed to a settlement term sheet to resolve the following shareholder
derivative lawsuits relating to HB 6 and the now former Ohio House Speaker Larry Householder and other individuals and
entities allegedly affiliated with Mr. Householder that were filed in the S.D. Ohio, the N.D. Ohio, and the Ohio Court of Common
Pleas, Summit County:
•
Gendrich v. Anderson, et al. and Sloan v. Anderson, et al. (Common Pleas Court, Summit County, OH, all actions have
been consolidated); on July 26, 2020 and July 31, 2020, respectively, purported stockholders of FE filed shareholder
derivative action lawsuits against certain FE directors and officers, alleging, among other things, breaches of fiduciary
duty.
• Miller v. Anderson, et al. (Federal District Court, N.D. Ohio); Bloom, et al. v. Anderson, et al.; Employees Retirement
System of the City of St. Louis v. Jones, et al.; Electrical Workers Pension Fund, Local 103, I.B.E.W. v. Anderson et al.;
Massachusetts Laborers Pension Fund v. Anderson et al.; The City of Philadelphia Board of Pensions and Retirement
v. Anderson et al.; Atherton v. Dowling et al.; Behar v. Anderson, et al. (Federal District Court, S.D. Ohio, all actions
have been consolidated); beginning on August 7, 2020, purported stockholders of FE filed shareholder derivative
actions alleging the FE Board and officers breached their fiduciary duties and committed violations of Section 14(a) of
the Exchange Act.
The proposed settlement, which is subject to court approval, will fully resolve the shareholder derivative lawsuits above and
stipulates a series of corporate governance enhancements, that is expected to result in the following:
•
•
•
•
•
•
Six members of the FE Board, Messrs. Michael J. Anderson, Donald T. Misheff, Thomas N. Mitchell, Christopher D.
Pappas and Luis A. Reyes, and Ms. Julia L. Johnson will not stand for re-election at FE’s 2022 annual shareholder
meeting;
A special FE Board committee of at least three recently appointed independent directors will be formed to initiate a
review process of the current senior executive team, to begin within 30 days of the 2022 annual shareholder meeting;
The FE Board will oversee FE’s lobbying and political activities, including periodically reviewing and approving political
and lobbying action plans prepared by management;
The FE Board will form another committee of recently appointed independent directors to oversee the implementation
and third-party audits of the FE Board-approved action plans with respect to political and lobbying activities;
FE will implement enhanced disclosure to shareholders of political and lobbying activities, including enhanced
disclosure in its annual proxy statement; and
FE will further align financial incentives of senior executives to proactive compliance with legal and ethical obligations.
The settlement also includes a payment to FirstEnergy of $180 million, to be paid by insurance after court approval, less any
court-ordered attorney’s fees awarded to plaintiffs.
In letters dated January 26, and February 22, 2021, staff of FERC's Division of Investigations notified FirstEnergy that the
Division is conducting an investigation of FirstEnergy’s lobbying and governmental affairs activities concerning HB 6, and staff
directed FirstEnergy to preserve and maintain all documents and information related to the same as such have been developed
as part of an ongoing non-public audit being conducted by FERC's Division of Audits and Accounting. While no contingency has
been reflected in the consolidated financial statements, FirstEnergy believes that it is probable that it will incur a loss in
46
connection with the resolution of the FERC investigation. Given the ongoing nature and complexity of the review, inquiries and
investigations, FirstEnergy cannot yet reasonably estimate a loss or range of loss that may arise from the resolution of the FERC
investigation.
The outcome of any of these lawsuits, governmental investigations and audit is uncertain and could have a material adverse
effect on FE’s or its subsidiaries’ reputation, business, financial condition, results of operations, liquidity, and cash flows.
Other Legal Matters
There are various lawsuits, claims (including claims for asbestos exposure) and proceedings related to FirstEnergy’s normal
business operations pending against FE or its subsidiaries. The loss or range of loss in these matters is not expected to be
material to FE or its subsidiaries. The other potentially material items not otherwise discussed above are described under Note
12, “Regulatory Matters.”
FirstEnergy accrues legal liabilities only when it concludes that it is probable that it has an obligation for such costs and can
reasonably estimate the amount of such costs. In cases where FirstEnergy determines that it is not probable, but reasonably
possible that it has a material obligation, it discloses such obligations and the possible loss or range of loss if such estimate can
be made. If it were ultimately determined that FE or its subsidiaries have legal liability or are otherwise made subject to liability
based on any of the matters referenced above, it could have a material adverse effect on FE’s or its subsidiaries’ financial
condition, results of operations and cash flows.
CRITICAL ACCOUNTING POLICIES AND ESTIMATES
FirstEnergy prepares consolidated financial statements in accordance with GAAP. Application of these principles often requires a
high degree of judgment, estimates and assumptions that affect financial results. FirstEnergy's accounting policies require
significant judgment regarding estimates and assumptions underlying the amounts included in the financial statements.
Additional information regarding the application of accounting policies is included in the Notes to Consolidated Financial
Statements.
Loss Contingencies
FirstEnergy is involved in a number of investigations, litigation, regulatory audits, arbitration, mediation, and similar proceedings,
including those surrounding HB 6. FirstEnergy regularly assesses its liabilities and contingencies in connection with asserted or
potential matters and establishes reserves when appropriate. In the preparation of the financial statements, FirstEnergy makes
judgments regarding the future outcome of contingent events based on currently available information and accrues liabilities
when it concludes that it is probable that it has an obligation for such costs and can reasonably estimate the amount of such
costs. In cases where FirstEnergy determines that it is not probable, but reasonably possible that it has a material obligation, it
discloses such obligations and the possible loss or range of loss if such estimate can be made. Circumstances change over time
and actual results may vary significantly from estimates. See Note 12, “Regulatory Matters” and Note 13, “Commitments,
Guarantees and Contingencies,” of the Notes to Consolidated Financial Statements for additional information.
Revenue Recognition
The accounting treatment for revenue recognition is based on the nature of the underlying transaction and applicable
authoritative guidance. FirstEnergy accounts for revenues from contracts with customers under ASC 606, “Revenue from
Contracts with Customers.” Revenue from leases, financial instruments, other contractual rights or obligations and other
revenues that are not from contracts with customers are outside the scope of the standard and accounted for under other
existing GAAP.
Contracts with Customers
FirstEnergy follows the accrual method of accounting for revenues, recognizing revenue for electricity that has been delivered to
customers but not yet billed through the end of the accounting period. The determination of electricity sales to individual
customers is based on meter readings, which occur on a systematic basis throughout the month. At the end of each month,
electricity delivered to customers since the last meter reading is estimated and a corresponding accrual for unbilled sales is
recognized. The determination of unbilled sales and revenues requires management to make estimates regarding electricity
available for retail load, transmission and distribution line losses, demand by customer class, applicable billing demands,
weather-related impacts, number of days unbilled and tariff rates in effect within each customer class.
The Transmission Companies revenues are primarily derived from forward-looking formula rates. Forward-looking formula rates
recover costs that the regulatory agencies determine are permitted to be recovered and provide a return on transmission capital
investment. Under forward-looking formula rates, the revenue requirement is updated annually based on a projected rate base
and projected costs, which is subject to an annual true-up based on actual costs. Revenues and cash receipts for the stand-
ready obligation of providing transmission service are recognized ratably over time.
47
FirstEnergy has elected the optional invoice practical expedient for most of its revenues and utilizes the optional short-term
contract exemption for transmission revenues due to the annual establishment of revenue requirements, which eliminates the
need to provide certain revenue disclosures regarding unsatisfied performance obligations. See Note 2, "Revenue," of the Notes
to Consolidated Financial Statements for additional information.
Regulatory Accounting
FirstEnergy’s Regulated Distribution and Regulated Transmission segments are subject to regulation that sets the prices (rates)
the Utilities and the Transmission Companies are permitted to charge customers based on costs that the regulatory agencies
determine are permitted to be recovered. At times, regulatory agencies permit the future recovery of costs that would be currently
charged to expense by an unregulated company. The ratemaking process results in the recording of regulatory assets and
liabilities based on anticipated future cash inflows and outflows.
FirstEnergy reviews the probability of recovery of regulatory assets, and settlement of regulatory liabilities, at each balance sheet
date and whenever new events occur. Factors that may affect probability include changes in the regulatory environment,
issuance of a regulatory commission order, or passage of new legislation. Upon material changes to these factors, where
applicable, FirstEnergy will record new regulatory assets or liabilities and will assess whether it is probable that currently
recorded regulatory assets and liabilities will be recovered or settled in future rates. If recovery of a regulatory asset is no longer
probable, FirstEnergy will write off that regulatory asset as a charge against earnings. FirstEnergy considers the entire regulatory
asset balance as the unit of account for the purposes of balance sheet classification rather than the next years recovery and as
such net regulatory assets and liabilities are presented in the non-current section on the FirstEnergy Consolidated Balance
Sheets. See Note 12, "Regulatory Matters," of the Notes to Consolidated Financial Statements for additional information.
Pension and OPEB Accounting
FirstEnergy provides noncontributory qualified defined benefit pension plans that cover substantially all of its employees and
non-qualified pension plans that cover certain employees. FirstEnergy provides a minimum amount of noncontributory life
insurance to retired employees in addition to optional contributory insurance. Health care benefits, which include certain
employee contributions, deductibles and co-payments, are also available upon retirement to certain employees, their dependents
and, under certain circumstances, their survivors. FirstEnergy also has obligations to former or inactive employees after
employment, but before retirement, for disability-related benefits.
FirstEnergy pension and OPEB obligations are based on various assumptions in calculating these amounts. These assumptions
include discount rates, health care cost trend rates, expected return on plan assets, compensation increases, retirement rates,
mortality rates, among others. Actual results that differ from the assumptions and changes in assumptions affect future expenses
and obligations.
Discount Rate - In selecting an assumed discount rate, FirstEnergy considers currently available rates of return on high-quality
fixed income investments expected to be available during the period to maturity of the pension and OPEB obligations.
FirstEnergy utilizes a full yield curve approach in the estimation of the service and interest components of net periodic benefit
costs for pension and other postretirement benefits by applying specific spot rates along the full yield curve to the relevant
projected cash flows.
Expected Return on Plan Assets - The expected return on pension and OPEB assets is based on input from investment
consultants, including the trusts’ asset allocation targets and the historical performance of risk-based and fixed income securities.
The gains or losses generated as a result of the difference between expected and actual returns on plan assets is recognized as
a pension and OPEB mark-to-market adjustment in the fourth quarter of each fiscal year and whenever a plan is determined to
qualify for remeasurement. The expected return on plan assets for 2022 is 7.50%.
Mortality Rates - The mortality assumption is composed of a base table that represents the current expectation of life
expectancy of the population adjusted by an improvement scale that attempts to anticipate future improvements in life
expectancy. The Pri-2012 mortality table with projection scale MP-2021, actuarially adjusted to reflect increased mortality rates
due to COVID-19 based on mortality experience reported by the Center for Disease and Control Prevention in 2020 and 2021,
was utilized to determine the 2021 benefit cost and obligation as of December 31, 2021, for FirstEnergy's pension and OPEB
plans. The MP-2021 scale was published in 2021 by the Society of Actuaries.
Health Care Trend Rates - In determining trend rate assumptions, included are the specific provisions of FirstEnergy’s health
care plans, the demographics and utilization rates of plan participants, actual cost increases experienced in FirstEnergy’s health
care plans, and projections of future medical trend rates.
Net Periodic Benefit Costs - In addition to service costs, interest on obligations, expected return on plan assets, and prior
service costs, FirstEnergy recognizes in net periodic benefit costs a pension and OPEB mark-to-market adjustment for the
change in the fair value of plan assets and net actuarial gains and losses annually in the fourth quarter of each fiscal year and
whenever a plan is determined to qualify for a remeasurement.
48
The following table reflects the portion of pension and OPEB costs that were charged to expense, including any pension and
OPEB mark-to-market adjustments, in the three years ended December 31, 2021, 2020, and 2019:
Net Periodic Benefit Costs (Credits)
2021
2020
(In millions)
2019
Pension
OPEB
Total
$
$
(582) $
(170)
(752) $
254 $
(47)
207 $
622
(21)
601
The annual pension and OPEB mark-to-market adjustments, (gains) or losses, for the years ended December 31, 2021, 2020,
and 2019 were $(382) million, $477 million, and $676 million, respectively.
FirstEnergy expects its 2022 pre-tax net periodic benefit credit including amounts capitalized (excluding mark-to-market
adjustments) to be approximately $233 million based upon the following assumptions:
Assumptions
Service cost weighted-average discount rate
Interest cost weighted-average discount rate
Expected return on plan assets
Pension
OPEB
3.28 %
2.44 %
7.50 %
3.41 %
2.18 %
7.50 %
The approximate effects on 2022 pension and OPEB net periodic benefit costs and the 2021 benefit obligation from changes in
key assumptions are as follows:
Approximate Effect on 2022 Net Periodic Benefit Costs from Changes in Key Assumptions
Assumption
Change
Pension
OPEB
Total
(In millions)
Discount rate
Change by 0.25% $
Expected return on plan assets Change by 0.25% $
Health care trend rate
Change by 1.0%
370 $
22 $
N/A $
13 $
1 $
10 $
383
23
10
Approximate Effect on 2021 Benefit Obligation from Changes in Key Assumptions
Assumption
Change
Pension
OPEB
Total
(In millions)
Discount rate
Change by 0.25% $
Health care trend rate
Change by 1.0%
375 $
N/A $
14 $
11 $
389
11
See Note 4, "Pension and Other Postemployment Benefits," of the Notes to Consolidated Financial Statements for additional
information.
Income Taxes
Judgment and the use of estimates are required in developing the provision for income taxes and reporting of tax-related assets
and liabilities such as the interpretation of tax laws and associated regulations. FirstEnergy is required to make judgments
regarding the potential tax effects of various transactions and results of operations in order to estimate its obligations to taxing
authorities.
Accounting for tax obligations requires judgments, including assessing whether tax benefits are more likely than not to be
sustained, and estimating reserves for potential adverse outcomes regarding tax positions that have been taken. FirstEnergy
records income taxes in accordance with the liability method of accounting. Deferred income taxes reflect the net tax effect of
temporary differences between the carrying amounts of assets and liabilities for financial reporting purposes and the amounts
recognized for tax purposes. Investment tax credits, which were deferred when utilized, are being amortized over the recovery
period of the related property. Deferred income tax liabilities related to temporary tax and accounting basis differences and tax
credit carryforward items are recognized at the statutory income tax rates in effect when the liabilities are expected to be paid.
Deferred tax assets are recognized based on income tax rates expected to be in effect when they are settled.
49
Actual income taxes could vary from estimated amounts due to the future impacts of various items, including future changes in
income tax laws, forecasted results of operations, failure to successfully implement tax planning strategies, as well as results of
audits and examinations of filed tax returns by taxing authorities.
See Note 6, "Taxes," of the Notes to Consolidated Financial Statements for additional information on income taxes.
NEW ACCOUNTING PRONOUNCEMENTS
See Note 1, "Organization and Basis of Presentation," of the Notes to Consolidated Financial Statements for a discussion of new
accounting pronouncements.
50
Report of Independent Registered Public Accounting Firm
To the Stockholders and Board of Directors of FirstEnergy Corp.
Opinions on the Financial Statements and Internal Control over Financial Reporting
We have audited the accompanying consolidated balance sheets of FirstEnergy Corp. and its subsidiaries (the “Company”) as of
December 31, 2021 and 2020, and the related consolidated statements of income, of comprehensive income, of stockholders’
equity and of cash flows for each of the three years in the period ended December 31, 2021, including the related notes
(collectively referred to as the “consolidated financial statements”). We also have audited the Company's internal control over
financial reporting as of December 31, 2021, based on criteria established in Internal Control - Integrated Framework (2013)
issued by the Committee of Sponsoring Organizations of the Treadway Commission (COSO).
In our opinion, the consolidated financial statements referred to above present fairly, in all material respects, the financial position
of the Company as of December 31, 2021 and 2020, and the results of its operations and its cash flows for each of the three
years in the period ended December 31, 2021 in conformity with accounting principles generally accepted in the United States of
America. Also in our opinion, the Company maintained, in all material respects, effective internal control over financial reporting
as of December 31, 2021, based on criteria established in Internal Control - Integrated Framework (2013) issued by the COSO.
Basis for Opinions
The Company's management is responsible for these consolidated financial statements, for maintaining effective internal control
over financial reporting, and for its assessment of the effectiveness of internal control over financial reporting, included in
Management's Report on Internal Control over Financial Reporting appearing under Item 9A. Our responsibility is to express
opinions on the Company’s consolidated financial statements and on the Company's internal control over financial reporting
based on our audits. We are a public accounting firm registered with the Public Company Accounting Oversight Board (United
States) (PCAOB) and are required to be independent with respect to the Company in accordance with the U.S. federal securities
laws and the applicable rules and regulations of the Securities and Exchange Commission and the PCAOB.
We conducted our audits in accordance with the standards of the PCAOB. Those standards require that we plan and perform the
audits to obtain reasonable assurance about whether the consolidated financial statements are free of material misstatement,
whether due to error or fraud, and whether effective internal control over financial reporting was maintained in all material
respects.
Our audits of the consolidated financial statements included performing procedures to assess the risks of material misstatement
of the consolidated financial statements, whether due to error or fraud, and performing procedures that respond to those risks.
Such procedures included examining, on a test basis, evidence regarding the amounts and disclosures in the consolidated
financial statements. Our audits also included evaluating the accounting principles used and significant estimates made by
management, as well as evaluating the overall presentation of the consolidated financial statements. Our audit of internal control
over financial reporting included obtaining an understanding of internal control over financial reporting, assessing the risk that a
material weakness exists, and testing and evaluating the design and operating effectiveness of internal control based on the
assessed risk. Our audits also included performing such other procedures as we considered necessary in the circumstances. We
believe that our audits provide a reasonable basis for our opinions.
Definition and Limitations of Internal Control over Financial Reporting
A company’s internal control over financial reporting is a process designed to provide reasonable assurance regarding the
reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally
accepted accounting principles. A company’s internal control over financial reporting includes those policies and procedures that
(i) pertain to the maintenance of records that, in reasonable detail, accurately and fairly reflect the transactions and dispositions
of the assets of the company; (ii) provide reasonable assurance that transactions are recorded as necessary to permit
preparation of financial statements in accordance with generally accepted accounting principles, and that receipts and
expenditures of the company are being made only in accordance with authorizations of management and directors of the
company; and (iii) provide reasonable assurance regarding prevention or timely detection of unauthorized acquisition, use, or
disposition of the company’s assets that could have a material effect on the financial statements.
Because of its inherent limitations, internal control over financial reporting may not prevent or detect misstatements. Also,
projections of any evaluation of effectiveness to future periods are subject to the risk that controls may become inadequate
because of changes in conditions, or that the degree of compliance with the policies or procedures may deteriorate.
Critical Audit Matters
The critical audit matter communicated below is a matter arising from the current period audit of the consolidated financial
statements that was communicated or required to be communicated to the audit committee and that (i) relates to accounts or
disclosures that are material to the consolidated financial statements and (ii) involved our especially challenging, subjective, or
complex judgments. The communication of critical audit matters does not alter in any way our opinion on the consolidated
financial statements, taken as a whole, and we are not, by communicating the critical audit matter below, providing a separate
opinion on the critical audit matter or on the accounts or disclosures to which it relates.
51
Accounting for the Effects of Rate Regulation
As described in Note 1 to the consolidated financial statements, the Company’s Regulated Distribution and Regulated
Transmission segments are subject to regulation that sets the prices (rates) the Company is permitted to charge customers
based on costs that the regulatory agencies determine are permitted to be recovered. At times, regulatory agencies permit the
future recovery of costs that would be currently charged to expense by an unregulated company. The ratemaking process results
in the recording of regulatory assets and liabilities based on anticipated future cash inflows and outflows. Management reviews
the probability of recovery of regulatory assets, and settlement of regulatory liabilities, at each balance sheet date and whenever
new events occur. Factors that may affect probability include changes in the regulatory environment, issuance of a regulatory
commission order, or passage of new legislation. Upon material changes to these factors, where applicable, management will
record new regulatory assets or liabilities and will assess whether it is probable that currently recorded regulatory assets and
liabilities will be recovered or settled in future rates. As of December 31, 2021, there were $71 million of regulatory assets and
$2,124 million of regulatory liabilities.
The principal considerations for our determination that performing procedures relating to management’s accounting for the
effects of rate regulation is a critical audit matter are the significant audit effort in assessing the impact of regulation on
accounting for regulatory assets and liabilities and in evaluating the complex audit evidence related to whether the regulatory
assets will be recovered and liabilities settled.
Addressing the matter involved performing procedures and evaluating audit evidence in connection with forming our overall
opinion on the consolidated financial statements. These procedures included testing the effectiveness of controls relating to the
accounting for regulatory matters, including controls over the evaluation of the recoverability and settlement of existing regulatory
assets and liabilities. These procedures also included, among others, obtaining the Company’s correspondence with regulators,
evaluating the reasonableness of management’s assessment regarding regulatory guidance, proceedings, and legislation and
the related accounting implications, and calculating regulatory assets and liabilities based on provisions outlined in rate orders
and other correspondence with regulators.
/s/ PricewaterhouseCoopers LLP
Cleveland, Ohio
February 16, 2022
We have served as the Company’s auditor since 2002.
52
FIRSTENERGY CORP.
CONSOLIDATED STATEMENTS OF INCOME
(In millions, except per share amounts)
REVENUES:
Distribution services and retail generation
Transmission
Other
Total revenues(1)
OPERATING EXPENSES:
Fuel
Purchased power
Other operating expenses
Provision for depreciation
Amortization (deferral) of regulatory assets, net
General taxes
DPA penalty (Note 13)
Gain on sale of Yards Creek (Note 12)
Total operating expenses
OPERATING INCOME
OTHER INCOME (EXPENSE):
Miscellaneous income, net
Pension and OPEB mark-to-market adjustment
Interest expense
Capitalized financing costs
Total other expense
INCOME BEFORE INCOME TAXES
INCOME TAXES
INCOME FROM CONTINUING OPERATIONS
Discontinued operations (Note 14)(2)
NET INCOME
INCOME ALLOCATED TO PREFERRED STOCKHOLDERS (Note 1)
NET INCOME ATTRIBUTABLE TO COMMON STOCKHOLDERS
EARNINGS PER SHARE OF COMMON STOCK:
Basic - Continuing Operations
Basic - Discontinued Operations
Basic - Net Income Attributable to Common Stockholders
Diluted - Continuing Operations
Diluted - Discontinued Operations
Diluted - Net Income Attributable to Common Stockholders
WEIGHTED AVERAGE NUMBER OF COMMON SHARES OUTSTANDING:
Basic
Diluted
For the Years Ended December 31,
2019
2020
2021
$
9,009 $
1,608
515
11,132
8,688 $
1,613
489
10,790
8,720
1,510
805
11,035
481
2,964
3,196
1,302
269
1,073
230
(109)
9,406
1,726
517
382
(1,141)
75
(167)
1,559
320
1,239
44
369
2,701
3,291
1,274
(53)
1,046
—
—
8,628
2,162
432
(477)
(1,065)
77
(1,033)
1,129
126
1,003
76
$
$
$
$
$
$
1,283 $
1,079 $
—
—
1,283 $
1,079 $
2.27 $
0.08
2.35 $
2.27 $
0.08
2.35 $
1.85 $
0.14
1.99 $
1.85 $
0.14
1.99 $
545
546
542
543
497
2,927
2,952
1,220
(79)
1,008
—
—
8,525
2,510
243
(674)
(1,033)
71
(1,393)
1,117
213
904
8
912
4
908
1.69
0.01
1.70
1.67
0.01
1.68
535
542
(1) Includes excise and gross receipts tax collections of $374 million, $362 million and $373 million in 2021, 2020 and 2019, respectively.
(2) Net of income tax benefit of $48 million, $59 million, and $5 million in 2021, 2020 and 2019, respectively.
The accompanying Notes to Consolidated Financial Statements are an integral part of these financial statements.
53
FIRSTENERGY CORP.
CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME
(In millions)
NET INCOME
OTHER COMPREHENSIVE INCOME (LOSS):
Pension and OPEB prior service costs
Amortized losses on derivative hedges
Other comprehensive loss
Income tax benefits on other comprehensive loss
Other comprehensive loss, net of tax
For the Years Ended December 31,
2021
2020
2019
$
1,283 $
1,079 $
912
(14)
1
(13)
(3)
(10)
(34)
1
(33)
(8)
(25)
(31)
2
(29)
(8)
(21)
COMPREHENSIVE INCOME
$
1,273 $
1,054 $
891
The accompanying Notes to Consolidated Financial Statements are an integral part of these financial statements.
54
FIRSTENERGY CORP.
CONSOLIDATED BALANCE SHEETS
(In millions, except share amounts)
ASSETS
CURRENT ASSETS:
Cash and cash equivalents
Restricted cash
Receivables-
Customers
Less — Allowance for uncollectible customer receivables
Other, net of allowance for uncollectible accounts of $10 in 2021 and $26 in 2020
Materials and supplies, at average cost
Prepaid taxes and other
PROPERTY, PLANT AND EQUIPMENT:
In service
Less — Accumulated provision for depreciation
Construction work in progress
PROPERTY, PLANT AND EQUIPMENT, NET - HELD FOR SALE (NOTE 13)
INVESTMENTS AND OTHER NONCURRENT ASSETS
Goodwill
Investments (Note 8)
Regulatory assets
Other
LIABILITIES AND CAPITALIZATION
CURRENT LIABILITIES:
Currently payable long-term debt
Short-term borrowings
Accounts payable
Accrued interest
Accrued taxes
Accrued compensation and benefits
Dividends payable (Note 9)
Other
CAPITALIZATION:
Stockholders’ equity-
Common stock, $0.10 par value, authorized 700,000,000 shares - 570,261,104 and 543,117,533
shares outstanding as of December 31, 2021 and 2020, respectively
Other paid-in capital
Accumulated other comprehensive loss
Accumulated deficit
Total stockholders' equity
Long-term debt and other long-term obligations
NONCURRENT LIABILITIES:
Accumulated deferred income taxes
Retirement benefits
Regulatory liabilities
Other
December 31,
2021
December 31,
2020
$
1,462 $
49
$
$
1,192
159
1,033
246
260
187
3,237
46,002
12,672
33,330
1,414
34,744
—
5,618
655
71
1,107
7,451
45,432 $
1,606 $
—
943
283
647
313
222
402
4,416
57
10,238
(15)
(1,605)
8,675
22,248
30,923
3,437
2,669
2,124
1,863
10,093
1,734
67
1,367
164
1,203
236
317
157
3,714
43,654
11,938
31,716
1,578
33,294
45
5,618
605
82
1,106
7,411
44,464
146
2,200
827
282
640
349
212
348
5,004
54
10,076
(5)
(2,888)
7,237
22,131
29,368
3,095
3,345
1,826
1,826
10,092
COMMITMENTS, GUARANTEES AND CONTINGENCIES (Note 13)
$
45,432 $
44,464
The accompanying Notes to Consolidated Financial Statements are an integral part of these financial statements.
55
FIRSTENERGY CORP.
CONSOLIDATED STATEMENTS OF STOCKHOLDERS' EQUITY
(In millions)
Shares Amount Shares Amount
OPIC
AOCI
Series A
Convertible
Preferred Stock
Common Stock
Accumulated
Deficit
Total
Stockholders'
Equity
Balance, January 1, 2019
0.7 $
71
512 $
51 $ 11,530 $
41 $
(4,879)
6,814
Net income
Other comprehensive loss, net of tax
Stock-based compensation
Cash dividends declared on common
stock
Cash dividends declared on preferred
stock
Stock Investment Plan and certain
share-based benefit plans
Conversion of Series A Convertible Stock
(0.7)
Balance, December 31, 2019
—
Net income
Other comprehensive loss, net of tax
Stock-based compensation
Cash dividends declared on common
stock
Stock Investment Plan and certain share-
based benefit plans
912
(21)
41
(824)
(3)
56
68
—
3
54
10,868
20
(3,967)
1,079
(25)
26
(846)
3
26
541
(71)
—
2
—
28
Balance, December 31, 2020
—
—
543
54
10,076
(5)
Net income
Other comprehensive loss, net of tax
Stock-based compensation
Cash dividends declared on common
stock
Common Stock issuance (Note 9)
Share-based benefit plans
(10)
26
(859)
971
24
26
1
3
(2,888)
1,283
912
(21)
41
(824)
(3)
56
—
6,975
1,079
(25)
26
(846)
28
7,237
1,283
(10)
26
(859)
974
24
Balance, December 31, 2021
— $
—
570 $
57 $ 10,238 $
(15) $
(1,605) $
8,675
Dividends declared for each share of common stock and as-converted share of preferred stock (applicable to 2019) were $1.56
during 2021 and 2020, as well as $1.53 during 2019.
The accompanying Notes to Consolidated Financial Statements are an integral part of these financial statements.
56
FIRSTENERGY CORP.
CONSOLIDATED STATEMENTS OF CASH FLOWS
(In millions)
CASH FLOWS FROM OPERATING ACTIVITIES:
Net income
Adjustments to reconcile net income to net cash from operating activities-
Depreciation and amortization
Retirement benefits, net of payments
Pension and OPEB mark-to-market adjustment
Deferred income taxes and investment tax credits, net
Asset removal costs charged to income
Transmission revenue collections, net
Gain on sale of Yards Creek
Pension trust contributions
Settlement agreement and tax sharing payments to the FES Debtors
Gain on disposal, net of tax (Note 14)
Changes in current assets and liabilities-
Receivables
Materials and supplies
Prepaid taxes and other
Accounts payable
Accrued taxes
Accrued interest
Accrued compensation and benefits
Other current liabilities
Cash collateral, net
Other
Net cash provided from operating activities
CASH FLOWS FROM FINANCING ACTIVITIES:
New financing-
Long-term debt
Short-term borrowings, net
Common stock issuance
Redemptions and repayments-
Long-term debt
Short-term borrowings, net
Preferred stock dividend payments
Common stock dividend payments
Other
Net cash provided from (used for) financing activities
CASH FLOWS FROM INVESTING ACTIVITIES:
Property additions
Proceeds from sale of Yards Creek
Sales of investment securities held in trusts
Purchases of investment securities held in trusts
Asset removal costs
Other
Net cash used for investing activities
Net change in cash, cash equivalents and restricted cash
Cash, cash equivalents, and restricted cash at beginning of period
Cash, cash equivalents, and restricted cash at end of period
SUPPLEMENTAL CASH FLOW INFORMATION:
Cash paid (received) during the year-
Interest (net of amounts capitalized)
Income taxes, net of refunds
For the Years Ended December 31,
2021
2020
2019
$
1,283 $
1,079 $
912
1,601
(417)
(382)
297
—
182
(109)
—
—
(47)
160
57
18
117
7
—
(36)
(16)
31
65
2,811
2,100
—
1,000
(532)
(2,200)
—
(849)
(61)
(542)
(2,445)
155
48
(59)
(226)
(32)
(2,559)
1,199
(301)
477
113
36
(32)
—
—
(978)
(76)
(129)
(32)
6
(138)
159
33
97
(16)
(12)
(62)
1,423
3,425
1,200
—
(1,114)
—
—
(845)
(59)
2,607
(2,657)
—
186
(208)
(224)
(5)
(2,908)
1,217
(108)
676
252
28
(55)
—
(500)
—
(59)
271
(37)
10
(49)
12
6
(60)
(21)
(10)
(18)
2,467
2,300
—
—
(789)
—
(6)
(814)
(35)
656
(2,665)
—
1,637
(1,675)
(217)
47
(2,873)
(290)
1,801
1,511 $
1,122
679
1,801 $
250
429
679
1,085 $
(7) $
970 $
6 $
960
12
$
$
$
The accompanying Notes to Consolidated Financial Statements are an integral part of these financial statements.
57
FIRSTENERGY CORP. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
Note
Number
Page
Number
1
Organization and Basis of Presentation ....................................................................................................
2
3
4
5
6
7
8
9
10
11
12
13
14
15
Revenue .........................................................................................................................................................
Accumulated Other Comprehensive Income ...........................................................................................
Pension and Other Postemployment Benefits .........................................................................................
Stock-Based Compensation Plans ............................................................................................................
Taxes ..............................................................................................................................................................
Leases ............................................................................................................................................................
Fair Value Measurements ...........................................................................................................................
Capitalization .................................................................................................................................................
Short-Term Borrowings and Bank Lines of Credit ...................................................................................
Asset Retirement Obligations .....................................................................................................................
Regulatory Matters .......................................................................................................................................
Commitments, Guarantees and Contingencies .......................................................................................
Discontinued Operations .............................................................................................................................
Segment Information ....................................................................................................................................
59
67
71
71
77
78
82
84
88
91
92
93
101
107
108
58
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
1. ORGANIZATION AND BASIS OF PRESENTATION
Unless otherwise indicated, defined terms and abbreviations used herein have the meanings set forth in the accompanying
Glossary of Terms.
FE was incorporated under Ohio law in 1996. FE’s principal business is the holding, directly or indirectly, of all of the outstanding
equity of its principal subsidiaries: OE, CEI, TE, Penn (a wholly owned subsidiary of OE), JCP&L, ME, PN, FESC, MP, AGC (a
wholly owned subsidiary of MP), PE, WP, and FET and its principal subsidiaries (ATSI, MAIT and TrAIL). In addition, FE holds all
of the outstanding equity of other direct subsidiaries including: AE Supply, FirstEnergy Properties, Inc., FEV, FirstEnergy License
Holding Company, GPUN, Allegheny Ventures, Inc., and Suvon, LLC, doing business as both FirstEnergy Home and FirstEnergy
Advisors.
FE does not bill directly or allocate any of its costs to any subsidiary company. Costs are charged to FE's subsidiaries for
services received from FESC either through direct billing or through an allocation process. Allocated costs are for services that
are provided on behalf of more than one company, or costs that cannot be precisely identified and are allocated using formulas
developed by FESC. Intercompany transactions are generally settled under commercial terms within thirty days.
FE and its subsidiaries are principally involved in the transmission, distribution, and generation of electricity. FirstEnergy’s ten
utility operating companies comprise one of the nation’s largest investor-owned electric systems, based on serving over six
million customers in the Midwest and Mid-Atlantic regions. FirstEnergy’s transmission operations include over 24,000 miles of
transmission lines and two regional transmission operation centers. AGC and MP control 3,580 MWs of total capacity.
PN, as lessee of the property of its subsidiary, the Waverly Electric Light & Power Company, serves approximately 4,000
customers in the Waverly, New York vicinity. On February 10, 2021, PN entered into an agreement to transfer its customers and
the related assets in Waverly, New York to Tri-County Rural Electric Cooperative; the completion of such transfer is subject to
several closing conditions including regulatory approval, which are ongoing, but is expected to have an immaterial impact to
FirstEnergy's financial statements.
FE and its subsidiaries follow GAAP and comply with the related regulations, orders, policies and practices prescribed by the
SEC, FERC, and, as applicable, the PUCO, the PPUC, the MDPSC, the NYPSC, the WVPSC, the VSCC and the NJBPU. The
preparation of financial statements in conformity with GAAP requires management to make periodic estimates and assumptions
that affect the reported amounts of assets, liabilities, revenues and expenses and disclosure of contingent assets and liabilities.
Actual results could differ from these estimates. The reported results of operations are not necessarily indicative of results of
operations for any future period. FE and its subsidiaries have evaluated events and transactions for potential recognition or
disclosure through the date the financial statements were issued.
FE and its subsidiaries consolidate all majority-owned subsidiaries over which they exercise control and, when applicable,
entities for which they have a controlling financial interest. Intercompany transactions and balances are eliminated in
consolidation as appropriate and permitted pursuant to GAAP. As further discussed below, FE and its subsidiaries consolidate a
VIE when it is determined that it is the primary beneficiary. Investments in affiliates over which FE and its subsidiaries have the
ability to exercise significant influence, but do not have a controlling financial interest, follow the equity method of accounting.
Under the equity method, the interest in the entity is reported as an investment in the Consolidated Balance Sheets and the
percentage of FE's ownership share of the entity’s earnings is reported in the Consolidated Statements of Income and
Comprehensive Income.
Certain prior year amounts have been reclassified to conform to the current year presentation.
COVID-19
FirstEnergy is continuously evaluating the global COVID-19 pandemic and taking steps to mitigate known risks. FirstEnergy is
actively monitoring the continued impact COVID-19 is having on its customers’ receivable balances, which include increasing
arrears balances since the pandemic began. FirstEnergy has incurred, and it is expected to incur for the foreseeable future,
COVID-19 pandemic related expenses. COVID-19 related expenses consist of additional costs that FirstEnergy is incurring to
protect its employees, contractors and customers, and to support social distancing requirements. These costs include, but are
not limited to, new or added benefits provided to employees, the purchase of additional personal protection equipment and
disinfecting supplies, additional facility cleaning services, COVID-19 test kits, initiated programs and communications to
customers on utility response, and increased technology expenses to support remote working, where possible. The full impact on
FirstEnergy’s business from the COVID-19 pandemic, including the governmental and regulatory responses, is unknown at this
time and difficult to predict. FirstEnergy provides a critical and essential service to its customers and the health and safety of its
employees, contractors and customers is its first priority. FirstEnergy is continuously monitoring its supply chain and is working
closely with essential vendors to understand the continued impact the COVID-19 pandemic is having on its business; however,
FirstEnergy does not currently expect disruptions in its ability to deliver service to customers or any material impact on its capital
investment spending plan.
59
FirstEnergy continues to effectively manage operations during the pandemic in order to provide critical service to customers and
believes it is well positioned to manage through the economic slowdown. FirstEnergy Distribution and Transmission revenues
benefit from geographic and economic diversity across a five-state service territory, which also allows for flexibility with capital
investments and measures to maintain sufficient liquidity over the next twelve months. However, the situation remains fluid and
future impacts to FirstEnergy that are presently unknown or unanticipated may occur. Furthermore, the likelihood of an impact to
FirstEnergy, and the severity of any impact that does occur, could increase the longer the global pandemic persists.
Sale of Minority Interest in FirstEnergy Transmission, LLC
On November 6, 2021, FirstEnergy, along with FET, entered into the FET P&SA, with Brookfield and Brookfield Guarantors,
pursuant to which FET agreed to issue and sell to Brookfield at the closing, and Brookfield agreed to purchase from FET, certain
newly issued membership interests of FET, such that Brookfield will own 19.9% of the issued and outstanding membership
interests of FET, for a purchase price of $2.375 billion. KATCo, which is currently a subsidiary of FET, will become a wholly
owned subsidiary of FE prior to the closing of the transaction and will remain in the Regulated Transmission segment. The
transaction is subject to customary closing conditions, including approval from the FERC and review by the CFIUS. On January
5, 2022, the parties to this transaction submitted to FERC an application requesting approval of the transaction no later than April
30, 2022, and on February 10, 2022, the parties filed answers in the FERC docket to certain protests that were filed on January
26, 2022.
Pursuant to the terms of the FET P&SA, in connection with the closing, Brookfield, FET and FirstEnergy Corp will enter into the
FET LLC Agreement. The FET LLC Agreement, among other things, provides for the governance, exit, capital and distribution,
and other arrangements for FET from and following the closing. Under the FET LLC Agreement, Brookfield will be entitled to
appoint a number of directors to the FET Board, in approximate proportion to Brookfield’s ownership percentage in FET (rounded
to the next whole number). Upon the closing, the FET Board will consist of five directors, one appointed by Brookfield and four
appointed by FE. The FET LLC Agreement contains certain investor protections, including, among other things, requiring
Brookfield's approval for FET and its subsidiaries to take certain major actions. Under the terms of the FET LLC Agreement, for
so long as Brookfield holds a 9.9% interest in FET, Brookfield’s consent is required for FET or any of its subsidiaries to incur
indebtedness (other than the refinancing of existing indebtedness on commercially reasonable terms reflecting then-current
credit market conditions) that would reasonably be expected to result in the FET’s consolidated Debt-to-Capital Ratio (as defined
in the FET LLC Agreement) equaling or exceeding (i) prior to the fifth anniversary of the effective date, 65%, and (ii) thereafter,
70%.
ACCOUNTING FOR THE EFFECTS OF REGULATION
FirstEnergy’s Regulated Distribution and Regulated Transmission segments are subject to regulation that sets the prices (rates)
the Utilities and the Transmission Companies are permitted to charge customers based on costs that the regulatory agencies
determine are permitted to be recovered. At times, regulatory agencies permit the future recovery of costs that would be currently
charged to expense by an unregulated company. The ratemaking process results in the recording of regulatory assets and
liabilities based on anticipated future cash inflows and outflows.
FirstEnergy reviews the probability of recovery of regulatory assets, and settlement of regulatory liabilities, at each balance sheet
date and whenever new events occur. Factors that may affect probability include changes in the regulatory environment,
issuance of a regulatory commission order, or passage of new legislation. Upon material changes to these factors, where
applicable, FirstEnergy will record new regulatory assets or liabilities and will assess whether it is probable that currently
recorded regulatory assets and liabilities will be recovered or settled in future rates. If recovery of a regulatory asset is no longer
probable, FirstEnergy will write off that regulatory asset as a charge against earnings. FirstEnergy considers the entire regulatory
asset balance as the unit of account for the purposes of balance sheet classification rather than the next years recovery and as
such net regulatory assets and liabilities are presented in the non-current section on the FirstEnergy Consolidated Balance
Sheets. See Note 12, "Regulatory Matters," of the Notes to Consolidated Financial Statements for additional information.
60
The following table provides information about the composition of net regulatory assets and liabilities as of December 31, 2021
and 2020, and the changes during the year ended December 31, 2021:
Net Regulatory Assets (Liabilities) by Source
2021
2020
Change
(In millions)
As of December 31,
Customer payables for future income taxes
$
(2,345) $
(2,369) $
Spent nuclear fuel disposal costs
Asset removal costs
Deferred transmission costs
Deferred generation costs
Deferred distribution costs
Contract valuations
Storm-related costs
Uncollectible and COVID-19 related costs
Energy efficiency program costs
New Jersey societal benefit costs
Regulatory transition costs
Vegetation management
Other
(101)
(646)
(3)
118
49
7
660
56
47
109
(18)
33
(19)
(102)
(721)
319
17
79
41
748
97
42
112
(20)
22
(9)
Net Regulatory Liabilities included on the Consolidated Balance Sheets
$
(2,053) $
(1,744) $
24
1
75
(322)
101
(30)
(34)
(88)
(41)
5
(3)
2
11
(10)
(309)
The following table provides information about the composition of net regulatory assets that do not earn a current return as of
December 31, 2021 and 2020, of which approximately $228 million and $195 million, respectively, are currently being recovered
through rates over varying periods, through 2068, depending on the nature of the deferral and the jurisdiction:
Regulatory Assets by Source Not Earning a
As of December 31,
Current Return
2021
2020
Change
Deferred transmission costs
Deferred generation costs
Storm-related costs
COVID-19 related costs
Regulatory transition costs
Vegetation management
Other
(in millions)
$
13 $
17 $
50
549
65
13
31
11
5
654
66
16
22
9
Regulatory Assets Not Earning a Current Return
$
732 $
789 $
DERIVATIVES
(4)
45
(105)
(1)
(3)
9
2
(57)
FirstEnergy is exposed to financial risks resulting from fluctuating interest rates and commodity prices, including prices for
electricity, coal and energy transmission. To manage the volatility related to these exposures, FirstEnergy’s Risk Policy
Committee, comprised of senior management, provides general management oversight for risk management activities
throughout FirstEnergy. The Risk Policy Committee is responsible for promoting the effective design and implementation of
sound risk management programs and oversees compliance with corporate risk management policies and established risk
management practice. FirstEnergy may use a variety of derivative instruments for risk management purposes including forward
contracts, options, futures contracts and swaps.
FirstEnergy accounts for derivative instruments on its Consolidated Balance Sheets at fair value unless they meet the normal
purchases and normal sales criteria. Derivative instruments meeting the normal purchases and normal sales criteria are
accounted for under the accrual method of accounting with their effects included in earnings at the time of contract performance.
EARNINGS PER SHARE OF COMMON STOCK
Basic EPS available to common stockholders is computed using the weighted average number of common shares outstanding
during the relevant period as the denominator. The denominator for diluted EPS of common stock reflects the weighted average
61
of common shares outstanding plus the potential additional common shares that could result if dilutive securities and other
agreements to issue common stock were exercised.
During 2019, EPS was computed using the two-class method required for participating securities. The convertible preferred stock
issued in January 2018 were considered participating securities since the shares participated in dividends on common stock on
an “as-converted” basis. All convertible preferred stock outstanding was converted to common stock during 2019.
The two-class method uses an earnings allocation formula that treats participating securities as having rights to earnings that
otherwise would have been available only to common stockholders. Under the two-class method, net income attributable to
common stockholders is derived by subtracting the following from income from continuing operations:
•
•
•
preferred stock dividends;
deemed dividends for the amortization of the beneficial conversion feature recognized at issuance of the preferred stock
(if any); and
an allocation of undistributed earnings between the common stock and the participating securities (convertible preferred
stock) based on their respective rights to receive dividends.
Net losses were not allocated to the convertible preferred stock as they did not have a contractual obligation to share in the
losses of FirstEnergy. FirstEnergy allocated undistributed earnings based upon income from continuing operations.
Diluted EPS reflects the dilutive effect of potential common shares from share-based awards and convertible shares of preferred
stock. The dilutive effect of outstanding share-based awards was computed using the treasury stock method, which assumes
any proceeds that could be obtained upon the exercise of the award would be used to purchase common stock at the average
market price for the period. The dilutive effect of the convertible preferred stock in 2019 was computed using the if-converted
method, which assumes conversion of the convertible preferred stock at the beginning of the period, giving income recognition
for the add-back of the preferred stock dividends and undistributed earnings allocated to preferred stockholders.
For the Years Ended December 31,
2021
2020
2019
$
1,239 $
1,003 $
904
N/A
N/A
N/A
N/A
(3)
(1)
900
8
—
8
Reconciliation of Basic and Diluted EPS of Common Stock
(In millions, except per share amounts)
EPS of Common Stock
Income from continuing operations
Less: Preferred dividends
Less: Undistributed earnings allocated to preferred stockholders
Income from continuing operations available to common stockholders
1,239
1,003
Discontinued operations, net of tax
Less: Undistributed earnings allocated to preferred stockholders
Income from discontinued operations available to common stockholders
44
N/A
44
76
N/A
76
Income attributable to common stockholders, basic
$
1,283 $
1,079 $
908
Income allocated to preferred stockholders, preferred dilutive
N/A
N/A
4
Income attributable to common stockholders, dilutive
$
1,283 $
1,079 $
912
Share Count information:
Weighted average number of basic shares outstanding
Assumed exercise of dilutive share based awards
Assumed conversion of preferred stock
Weighted average number of diluted shares outstanding
Income attributable to common stockholders, per common share:
Income from continuing operations, basic
Discontinued operations, basic
Income attributable to common stockholders, basic
Income from continuing operations, diluted
Discontinued operations, diluted
Income attributable to common stockholders, diluted
545
1
N/A
546
542
1
N/A
543
$
$
$
$
2.27 $
1.85 $
0.08
0.14
2.35 $
1.99 $
2.27 $
1.85 $
0.08
0.14
2.35 $
1.99 $
535
3
4
542
1.69
0.01
1.70
1.67
0.01
1.68
62
For the years ended December 31, 2021, 2020 and 2019 there were no material amount of shares excluded from the calculation
of diluted shares outstanding, as their inclusion would be antidilutive.
GOODWILL
In a business combination, the excess of the purchase price over the estimated fair value of the assets acquired and liabilities
assumed is recognized as goodwill. FirstEnergy evaluates goodwill for impairment annually on July 31 and more frequently if
indicators of impairment arise. In evaluating goodwill for impairment, FirstEnergy assesses qualitative factors to determine
whether it is more likely than not (that is, likelihood of more than 50%) that the fair value of a reporting unit is less than its
carrying value (including goodwill). If FirstEnergy concludes that it is not more likely than not that the fair value of a reporting unit
is less than its carrying value, then no further testing is required. However, if FirstEnergy concludes that it is more likely than not
that the fair value of a reporting unit is less than its carrying value or bypasses the qualitative assessment, then the quantitative
goodwill impairment test is performed to identify a potential goodwill impairment and measure the amount of impairment to be
recognized, if any.
As of July 31, 2021, FirstEnergy performed a qualitative assessment of the Regulated Distribution and Regulated Transmission
reporting units' goodwill, assessing economic, industry and market considerations in addition to the reporting units' overall
financial performance. Key factors used in the assessment included: growth rates, interest rates, expected investments, utility
sector market performance, regulatory and legal developments, and other market considerations. It was determined that the fair
values of these reporting units were, more likely than not, greater than their carrying values and a quantitative analysis was not
necessary.
FirstEnergy's reporting units are consistent with its reportable segments and consist of Regulated Distribution and Regulated
Transmission. The following table presents goodwill by reporting unit as of December 31, 2021:
(In millions)
Goodwill
INVENTORY
Regulated
Distribution
$
5,004 $
Regulated
Transmission Consolidated
5,618
614 $
Materials and supplies inventory includes fuel inventory and the distribution, transmission and generation plant materials, net of
reserve for excess and obsolete inventory. Materials charged to inventory are at weighted average cost when purchased and
expensed or capitalized, as appropriate, when used or installed. Fuel inventory is accounted for at weighted average cost when
purchased and recorded to fuel expense when consumed.
PROPERTY, PLANT AND EQUIPMENT
Property, plant and equipment reflects original cost (net of any impairments recognized), including payroll and related costs such
as taxes, employee benefits, administrative and general costs, and financing costs incurred to place the assets in service. The
costs of normal maintenance, repairs and minor replacements are expensed as incurred. FirstEnergy recognizes liabilities for
planned major maintenance projects as they are incurred. Property, plant and equipment balances by segment as of
December 31, 2021 and 2020, were as follows:
Property, Plant and Equipment
In Service(1)
Accum. Depr.
December 31, 2021
Net Plant
(In millions)
CWIP
Total
Regulated Distribution
Regulated Transmission
Corporate/Other
Total
$
$
31,154 $
(9,284) $
21,870 $
774 $
13,744
1,104
(2,789)
(599)
10,955
505
580
60
22,644
11,535
565
46,002 $
(12,672) $
33,330 $
1,414 $
34,744
Property, Plant and Equipment
In Service(1)
Accum. Depr.
Net Plant
CWIP
Total
December 31, 2020
(In millions)
Regulated Distribution
$
29,775 $
(8,800) $
20,975 $
841 $
Regulated Transmission
Corporate/Other
Total
12,912
1,039
(2,609)
(556)
10,303
483
671
66
$
43,726 $
(11,965) $
31,761 $
1,578 $
33,339
21,816
10,974
549
(1) Includes finance leases of $143 million and $153 million as of December 31, 2021 and 2020, respectively.
63
Regulated Distribution has approximately $2.1 billion of total regulated generation property, plant and equipment as of
December 31, 2021. Included within the Regulated Distribution segment is $45 million of assets classified as held for sale as of
December 31, 2020 associated with the asset purchase agreement with Yards Creek; see Note 12, "Regulatory Matters," for
additional information.
FirstEnergy provides for depreciation on a straight-line basis at various rates over the estimated lives of property included in
plant in service. The respective annual composite depreciation rates for FirstEnergy were approximately 2.7% in each 2021,
2020 and 2019.
For the years ended December 31, 2021, 2020 and 2019, capitalized financing costs on FirstEnergy's Consolidated Statements
of Income include $48 million, $49 million and $45 million, respectively, of allowance for equity funds used during construction
and $27 million, $28 million and $26 million, respectively, of capitalized interest.
Jointly Owned Plants
FE, through its subsidiary, AGC, owns an undivided 16.25% interest (487 MWs) in the 3,003 MW Bath County pumped-storage,
hydroelectric station in Virginia, operated by the 60% owner, VEPCO, a non-affiliated utility. Total property, plant and equipment
includes $153 million representing AGC's share in this facility as of December 31, 2021. AGC is obligated to pay its share of the
costs of this jointly owned facility in the same proportion as its ownership interests using its own financing. AGC's share of direct
expenses of the joint plant is included in operating expenses on FirstEnergy's Consolidated Statements of Income. AGC provides
the generation capacity from this facility to its owner, MP.
Asset Retirement Obligations
FirstEnergy recognizes an ARO for its legal obligation to perform asset retirement activities associated with its long-lived assets.
The ARO liability represents an estimate of the fair value of FirstEnergy's current obligation such that the ARO is accreted
monthly to reflect the time value of money.
A fair value measurement inherently involves uncertainty in the amount and timing of settlement of the liability. FirstEnergy uses
an expected cash flow approach to measure the fair value of the remediation AROs, considering the expected timing of
settlement of the ARO based on the expected economic useful life of associated asset and/or regulatory requirements. The fair
value of an ARO is recognized in the period in which it is incurred. The associated asset retirement costs are capitalized as part
of the carrying value of the long-lived asset and are depreciated over the life of the related asset. In certain circumstances,
FirstEnergy has recovery of asset retirement costs and, as such, certain accretion and depreciation is offset against regulatory
assets. Conditional retirement obligations associated with tangible long-lived assets are recognized at fair value in the period in
which they are incurred if a reasonable estimate can be made, even though there may be uncertainty about timing or method of
settlement. When settlement is conditional on a future event occurring, it is reflected in the measurement of the liability, not the
timing of the liability recognition.
AROs as of December 31, 2021, are described further in Note 11, "Asset Retirement Obligations."
Asset Impairments
FirstEnergy evaluates long-lived assets classified as held and used for impairment when events or changes in circumstances
indicate the carrying value of the long-lived assets may not be recoverable. First, the estimated undiscounted future cash flows
attributable to the assets is compared with the carrying value of the assets. If the carrying value is greater than the undiscounted
future cash flows, an impairment charge is recognized equal to the amount the carrying value of the assets exceeds its estimated
fair value.
64
RECEIVABLES
Receivables from customers include retail electric sales and distribution deliveries to residential, commercial and industrial
customers of the Utilities. There was no material concentration of receivables as of December 31, 2021 and 2020, with respect to
any particular segment of FirstEnergy’s customers. Billed and unbilled customer receivables as of December 31, 2021 and 2020,
are included below.
Customer Receivables
Billed(1)
Unbilled
Less: Uncollectible Reserve
Total Customer Receivables
As of December 31,
2021
2020
(In millions)
616 $
576
1,192
159
1,033 $
800
567
1,367
164
1,203
$
$
(1) Includes approximately $318 million and $349 million as of December 31, 2021, 2020, respectively, that are past due by greater than 30 days.
Activity in the allowance for uncollectible accounts on receivables for the years ended December 31, 2021, 2020 and 2019 are
as follows:
(In millions)
2021
2020
2019
Customer Receivables
Beginning of year balance
Charged to income (1)
Charged to other accounts (2)
Write-offs
End of year balance
Other Receivables
Beginning of year balance
Charged to income
Charged to other accounts (2)
Write-offs
End of year balance
Affiliated Companies Receivables (3)
Beginning of year balance
Charged to income
Charged to other accounts (2)
Write-offs
End of year balance
$
$
$
$
$
$
164 $
46 $
54
42
(101)
159 $
174
46
(102)
164 $
26 $
21 $
3
3
(22)
10 $
7
10
(12)
26 $
— $
1,063 $
—
—
—
—
—
(1,063)
50
81
47
(132)
46
2
27
1
(9)
21
920
143
—
—
— $
— $
1,063
(1) Customer receivable amounts charged to income for the years ended December 31, 2021, 2020 and 2019 include approximately $12 million,
$103 million, and $25 million respectively, deferred for future recovery.
(2) Represents recoveries and reinstatements of accounts previously written off for uncollectible accounts.
(3) Amounts relate to the FES Debtors and are included in discontinued operations. Write-off of $1.1 billion in 2020 was recognized upon their
emergence in February 2020.
The allowance for uncollectible customer receivables is based on historical loss information comprised of a rolling 36-month
average net write-off percentage of revenues, in conjunction with a qualitative assessment of elements that impact the
collectability of receivables to determine if allowances for uncollectible accounts should be further adjusted in accordance with
the accounting guidance for credit losses. Management contemplates available current information such as changes in economic
factors, regulatory matters, industry trends, customer credit factors, amount of receivable balances that are past-due, payment
options and programs available to customers, and the methods that the Utilities are able to utilize to ensure payment.
FirstEnergy reviews its allowance for uncollectible customer receivables utilizing a quantitative and qualitative assessment, which
includes consideration of the outbreak of COVID-19 and the impact on customer receivable balances outstanding and write-offs
since the pandemic began.
65
Beginning March 13, 2020, FirstEnergy temporarily suspended customer disconnections for nonpayment and ceased collection
activities as a result of the ongoing COVID-19 pandemic and in accordance with state regulatory requirements. The temporary
suspension of disconnections for nonpayment and ceasing of collection activities extended into the fourth quarter of 2020 but
resumed for many customers before the end of 2020, except in New Jersey where the moratorium was extended until the end of
2021. Customers are subject to each state's applicable regulations on winter moratoriums. See Note 12, “Regulatory Matters,”
for further discussion on applicable regulations that may alter customer disconnections and collection activity as well as
regulatory recovery. During 2020, FirstEnergy analyzed the likelihood of loss based on increases in customer accounts in arrears
since the pandemic began in mid-March 2020 as well as what collection methods at the time were suspended, and historically
been utilized to ensure payment. Based on this assessment, and consideration of other qualitative factors described above,
FirstEnergy recognized incremental uncollectible expense of $121 million in the year 2020, of which approximately $90 million
was not being collected through rates and as a result was deferred for future recovery under regulatory mechanisms.
During 2021, arrears levels continue to be elevated above 2019 pre-pandemic levels. Various regulatory actions have impacted
the growth and recovery of past due balances including extensions on moratoriums, significant restrictions regarding
disconnections, and extended installment plans. FirstEnergy has experienced a reduction in the amount of receivables that are
past due by greater than 30 days since the end of 2020. While total customer arrears balances continue to decrease in 2021,
balances that are over 120 days past due continue to be elevated. FirstEnergy considered other factors as part of its qualitative
assessment, such as certain federal stimulus and state funding being made available to assist with past due utility bills. As a
result of this qualitative analysis, FirstEnergy did not recognize any incremental uncollectible expense for the twelve months
ended December 31, 2021. Additionally, as a result of the pandemic-related moratoriums and certain customer installment or
extended payment plans offered, the allowance for uncollectible accounts on receivables in 2021 and 2020 are elevated due to
the extension of when certain write-offs would have otherwise occurred.
Other receivables include PJM receivables resulting from transmission and wholesale sales. FirstEnergy’s uncollectible risk on
PJM receivables is minimal due to the nature of PJM’s settlement process whereby members of PJM legally agree to share the
cost of defaults and as a result there is no allowance for doubtful accounts.
VARIABLE INTEREST ENTITIES
FirstEnergy performs qualitative analyses based on control and economics to determine whether a variable interest classifies
FirstEnergy as the primary beneficiary (a controlling financial interest) of a VIE. An enterprise has a controlling financial interest if
it has both power and economic control, such that an entity has: (i) the power to direct the activities of a VIE that most
significantly impact the entity’s economic performance; and (ii) the obligation to absorb losses of the entity that could potentially
be significant to the VIE or the right to receive benefits from the entity that could potentially be significant to the VIE. FirstEnergy
consolidates a VIE when it is determined that it is the primary beneficiary.
In order to evaluate contracts for consolidation treatment and entities for which FirstEnergy has an interest, FirstEnergy
aggregates variable interests into categories based on similar risk characteristics and significance.
Consolidated VIEs
VIEs in which FirstEnergy is the primary beneficiary consist of the following (included in FirstEnergy’s consolidated financial
statements):
•
Ohio Securitization - In June 2013, SPEs formed by the Ohio Companies issued approximately $445 million of pass-
through trust certificates supported by phase-in recovery bonds to securitize the recovery of certain all electric customer
heating discounts, fuel and purchased power regulatory assets.
• MP and PE Environmental Funding Companies - Bankruptcy remote, special purpose limited liability companies that are
indirect subsidiaries of MP and PE which issued environmental control bonds.
See Note 9, “Capitalization,” for additional information on securitized bonds.
Unconsolidated VIEs
FirstEnergy is not the primary beneficiary of the following VIEs:
•
•
Global Holding - FEV holds a 33-1/3% equity ownership in Global Holding, the holding company for a joint venture in
the Signal Peak mining and coal transportation operations with coal sales in U.S. and international markets. FEV is not
the primary beneficiary of the joint venture, as it does not have control over the significant activities affecting the joint
ventures economic performance. FEV's ownership interest is subject to the equity method of accounting. As of
December 31, 2021, the carrying value of the equity method investment was $59 million.
PATH WV - PATH, a proposed transmission line from West Virginia through Virginia into Maryland which PJM cancelled
in 2012, is a series limited liability company that is comprised of multiple series, each of which has separate rights,
powers and duties regarding specified property and the series profits and losses associated with such property. A
subsidiary of FE owns 100% of the Allegheny Series (PATH-Allegheny) and 50% of the West Virginia Series (PATH-
WV), which is a joint venture with a subsidiary of AEP. FirstEnergy is not the primary beneficiary of PATH-WV, as it does
not have control over the significant activities affecting the economics of PATH-WV. FirstEnergy's ownership interest in
66
PATH-WV is subject to the equity method of accounting. As of December 31, 2021, the carrying value of the equity
method investment was $18 million.
•
Purchase Power Agreements - FirstEnergy evaluated its PPAs and determined that certain NUG entities at its
Regulated Distribution segment may be VIEs to the extent that they own a plant that sells substantially all of its output to
the applicable utilities and the contract price for power is correlated with the plant’s variable costs of production.
FirstEnergy maintains six long-term PPAs with NUG entities that were entered into pursuant to PURPA. FirstEnergy was
not involved in the creation of, and has no equity or debt invested in, any of these entities. FirstEnergy has determined
that for all but one of these NUG entities, it does not have a variable interest, or the entities do not meet the criteria to
be considered a VIE. FirstEnergy may hold a variable interest in the remaining one entity; however, it applied the scope
exception that exempts enterprises unable to obtain the necessary information to evaluate entities.
Because FirstEnergy has no equity or debt interests in the NUG entities, its maximum exposure to loss relates primarily
to the above-market costs incurred for power. FirstEnergy expects any above-market costs incurred at its Regulated
Distribution segment to be recovered from customers. Purchased power costs related to the contract that may contain a
variable interest were $111 million and $113 million, respectively, during the years ended December 31, 2021 and 2020.
NEW ACCOUNTING PRONOUNCEMENTS
Recently Adopted Pronouncements
ASU 2019-12, "Simplifying the Accounting for Income Taxes" (Issued in December 2019): ASU 2019-12 enhances and simplifies
various aspects of the income tax accounting guidance, including the elimination of certain exceptions related to the approach for
intra-period tax allocation, the methodology for calculating income taxes in an interim period and the recognition of deferred tax
liabilities for outside basis differences. The new guidance also simplifies aspects of the accounting for franchise taxes and
enacted changes in tax laws or rates and clarifies the accounting for transactions that result in a step-up in the tax basis of
goodwill. FirstEnergy adopted the guidance as of January 1, 2021, with no material impact to the financial statements.
Recently Issued Pronouncements - FirstEnergy has assessed new authoritative accounting guidance issued by the FASB that
has not yet been adopted and none are currently expected to have a material impact to the financial statements.
2. REVENUE
FirstEnergy accounts for revenues from contracts with customers under ASC 606, “Revenue from Contracts with Customers.”
Revenue from leases, financial instruments, other contractual rights or obligations and other revenues that are not from contracts
with customers are outside the scope of the standard and accounted for under other existing GAAP.
FirstEnergy has elected to exclude sales taxes and other similar taxes collected on behalf of third parties from revenue as
prescribed in the standard. As a result, tax collections and remittances are excluded from recognition in the income statement
and instead recorded through the balance sheet. Excise and gross receipts taxes that are assessed on FirstEnergy are not
subject to the election and are included in revenue. FirstEnergy has elected the optional invoice practical expedient for most of
its revenues and utilizes the optional short-term contract exemption for transmission revenues due to the annual establishment of
revenue requirements, which eliminates the need to provide certain revenue disclosures regarding unsatisfied performance
obligations.
FirstEnergy’s revenues are primarily derived from electric service provided by the Utilities and Transmission Companies.
67
The following represents a disaggregation of revenue from contracts with customers for the year ended December 31, 2021:
Revenues by Type of Service
Regulated
Distribution
Regulated
Transmission
Corporate/Other
and Reconciling
Adjustments(1)
Total
(In millions)
Distribution services(2)(4)
$
5,433 $
— $
Retail generation
Wholesale sales
Transmission(2)
Other
3,730
362
—
119
—
—
1,608
—
(104) $
(50)
14
—
—
5,329
3,680
376
1,608
119
Total revenues from contracts with customers
$
9,644 $
1,608 $
(140) $
11,112
ARP (3)
Other revenue unrelated to contracts with customers
(27)
94
—
10
—
(57)
(27)
47
Total revenues
$
9,711 $
1,618 $
(197) $
11,132
(1) Includes eliminations and reconciling adjustments of inter-segment revenues.
(2) Includes reductions to revenue related to amounts subject to refund resulting from the Tax Act ($3 million at Regulated Distribution and $(2)
million at Regulated Transmission).
(3) Reflects amounts the Ohio Companies refunded to customers that was previously collected under decoupling mechanisms, with interest. See
Note 12, “Regulatory Matters,” for further discussion on Ohio decoupling rates.
(4) Includes $38 million of customer refunds associated with the Ohio Stipulation that became effective in December 2021. See Note 12,
“Regulatory Matters,” for additional information.
The following represents a disaggregation of revenue from contracts with customers for the year ended December 31, 2020:
Revenues by Type of Service
Distribution services(2)
Retail generation
Wholesale sales
Transmission(2)
Other
Regulated
Distribution
Regulated
Transmission
Corporate/Other
and Reconciling
Adjustments (1)
Total
$
5,259 $
— $
(In millions)
3,577
251
—
140
—
—
1,613
—
(88) $
(60)
9
—
—
5,171
3,517
260
1,613
140
Total revenues from contracts with customers
$
9,227 $
1,613 $
(139) $
10,701
ARP (3)
Other revenue unrelated to contracts with customers
43
93
—
17
—
(64)
43
46
Total revenues
$
9,363 $
1,630 $
(203) $
10,790
(1) Includes eliminations and reconciling adjustments of inter-segment revenues.
(2) Includes reductions to revenue related to amounts subject to refund resulting from the Tax Act ($2 million at Regulated Distribution and $7
million at Regulated Transmission).
(3) ARP revenue for the year ended December 31, 2020, is primarily related to shared savings revenue in Ohio.
68
The following represents a disaggregation of revenue from contracts with customers for the year ended December 31, 2019:
Revenues by Type of Service
Distribution services(2)
Retail generation
Wholesale sales(2)
Transmission(2)
Other
Regulated
Distribution
Regulated
Transmission
Corporate/Other
and Reconciling
Adjustments (1)
Total
$
5,133 $
— $
(In millions)
3,727
411
—
150
—
—
1,510
—
(83) $
(57)
12
—
2
5,050
3,670
423
1,510
152
Total revenues from contracts with customers
$
9,421 $
1,510 $
(126) $
10,805
ARP (3)
Other revenue unrelated to contracts with customers
181
96
—
16
—
(63)
181
49
Total revenues
$
9,698 $
1,526 $
(189) $
11,035
(1) Includes eliminations and reconciling adjustments of inter-segment revenues.
(2) Includes reductions to revenue related to amounts subject to refund resulting from the Tax Act ($16 million at Regulated Distribution and $19
million at Regulated Transmission).
(3) ARP revenue for the year ended December 31, 2019, includes DMR revenue, lost distribution and shared savings revenue in Ohio.
Other revenue unrelated to contracts with customers includes revenue from late payment charges of $36 million, $31 million and
$37 million, respectively, for the years ended December 31, 2021, 2020 and 2019. Other revenue unrelated to contracts with
customers also includes revenue from derivatives of $11 million, $14 million and $8 million, respectively, for the years ended
December 31, 2021, 2020 and 2019.
Regulated Distribution
The Regulated Distribution segment distributes electricity through FirstEnergy’s ten utility operating companies and also
controls 3,580 MWs of regulated electric generation capacity located primarily in West Virginia and Virginia. Each of the Utilities
earns revenue from state-regulated rate tariffs under which it provides distribution services to residential, commercial and
industrial customers in its service territory. The Utilities are obligated under the regulated construct to deliver power to customers
reliably, as it is needed, which creates an implied monthly contract with the end-use customer. See Note 12, “Regulatory
Matters,” for additional information on rate recovery mechanisms. Distribution and electric revenues are recognized over time as
electricity is distributed and delivered to the customer and the customers consume the electricity immediately as delivery occurs.
Retail generation sales relate to POLR, SOS, SSO and default service requirements in Ohio, Pennsylvania, New Jersey and
Maryland, as well as generation sales in West Virginia that are regulated by the WVPSC. Certain of the Utilities have default
service obligations to provide power to non-shopping customers who have elected to continue to receive service under regulated
retail tariffs. The volume of these sales varies depending on the level of shopping that occurs. Supply plans vary by state and by
service territory. Default service for the Ohio Companies, Pennsylvania Companies, JCP&L and PE’s Maryland jurisdiction are
provided through a competitive procurement process approved by each state’s respective commission. Retail generation
revenues are recognized over time as electricity is delivered and consumed immediately by the customer.
The following table represents a disaggregation of the Regulated Distribution segment revenue from contracts with distribution
service and retail generation customers for the years ended December 31, 2021, 2020 and 2019 by class:
Revenues by Customer Class
2021
2020
(In millions)
2019
For the Years Ended December 31,
Residential
Commercial
Industrial
Other
Total
$
$
5,713 $
5,539 $
2,284
1,091
75
2,140
1,076
81
9,163 $
8,836 $
5,412
2,252
1,106
90
8,860
Wholesale sales primarily consist of generation and capacity sales into the PJM market from FirstEnergy’s regulated electric
generation capacity and NUGs. Certain of the Utilities may also purchase power in the PJM markets to supply power to their
customers. Generally, these power sales from generation and purchases to serve load are netted hourly and reported as either
revenues or purchased power on the Consolidated Statements of Income based on whether the entity was a net seller or buyer
69
each hour. Capacity revenues are recognized ratably over the PJM planning year at prices cleared in the annual PJM Reliability
Pricing Model Base Residual Auction and Incremental Auctions. Capacity purchases and sales through PJM capacity auctions
are reported within revenues on the Consolidated Statements of Income. Certain capacity income (bonuses) and charges
(penalties) related to the availability of units that have cleared in the auctions are unknown and not recorded in revenue until, and
unless, they occur.
The Utilities’ distribution customers are metered on a cycle basis. An estimate of unbilled revenues is calculated to recognize
electric service provided from the last meter reading through the end of the month. This estimate includes many factors, among
which are historical customer usage, load profiles, estimated weather impacts, customer shopping activity and prices in effect for
each class of customer. In each accounting period, the Utilities accrue the estimated unbilled amount as revenue and reverse the
related prior period estimate. Customer payments vary by state but are generally due within 30 days.
ASC 606 excludes industry-specific accounting guidance for recognizing revenue from ARPs as these programs represent
contracts between the utility and its regulators, as opposed to customers. Therefore, revenues from these programs are not
within the scope of ASC 606 and regulated utilities are permitted to continue to recognize such revenues in accordance with
existing practice but are presented separately from revenue arising from contracts with customers. FirstEnergy had ARPs in Ohio
primarily for shared savings in 2020, and has reflected refunds of decoupling revenue owed to customers as reductions to ARPs
in 2021. See Note 12, “Regulatory Matters,” for further discussion on decoupling revenues in Ohio.
Regulated Transmission
The Regulated Transmission segment provides transmission infrastructure owned and operated by the Transmission
Companies and certain of FirstEnergy's utilities (JCP&L, MP, PE and WP) to transmit electricity from generation sources to
distribution facilities. The segment's revenues are derived from forward-looking formula rates. See Note 12, “Regulatory Matters,”
for additional information.
Forward-looking formula rates recover costs that the regulatory agencies determine are permitted to be recovered and provide a
return on transmission capital investment. Under forward-looking formula rates, the revenue requirement is updated annually
based on a projected rate base and projected costs, which is subject to an annual true-up based on actual costs. Revenues and
cash receipts for the stand-ready obligation of providing transmission service are recognized ratably over time.
The following table represents a disaggregation of revenue from contracts with regulated transmission customers for the years
ended December 31, 2021, 2020 and 2019:
Transmission Owner
2021
2020
(In millions)
2019
For the Years Ended December 31,
ATSI
TrAIL
MAIT
JCP&L
MP, PE and WP
Total Revenues
$
799 $
804 $
233
288
164
124
247
250
178
134
754
242
224
160
130
$
1,608 $
1,613 $
1,510
70
3. ACCUMULATED OTHER COMPREHENSIVE INCOME
The changes in AOCI for the years ended December 31, 2021, 2020 and 2019, for FirstEnergy are shown in the following table:
AOCI Balance, January 1, 2019
$
(11) $
52 $
Gains & Losses on
Cash Flow Hedges (1)
Defined Benefit
Pension & OPEB
Plans
(In millions)
Total
Other comprehensive income before reclassifications
Amounts reclassified from AOCI
Other comprehensive income (loss)
Income tax (benefits) on other comprehensive income (loss)
Other comprehensive income (loss), net of tax
AOCI Balance, December 31, 2019
Amounts reclassified from AOCI
Other comprehensive income (loss)
Income tax (benefits) on other comprehensive income (loss)
Other comprehensive income (loss), net of tax
AOCI Balance, December 31, 2020
Amounts reclassified from AOCI
Other comprehensive income (loss)
Income tax (benefits) on other comprehensive income (loss)
Other comprehensive income (loss), net of tax
AOCI Balance, December 31, 2021
$
$
$
—
2
2
—
2
(9) $
1
1
—
1
(8) $
1
1
—
1
(7) $
(2)
(29)
(31)
(8)
(23)
29 $
(34)
(34)
(8)
(26)
3 $
(14)
(14)
(3)
(11)
(8) $
41
(2)
(27)
(29)
(8)
(21)
20
(33)
(33)
(8)
(25)
(5)
(13)
(13)
(3)
(10)
(15)
(1) Relates to previous cash flow hedges used to hedge fixed rate long-term debt securities prior to their issuance.
The following amounts were reclassified from AOCI for FirstEnergy in the years ended December 31, 2021, 2020 and 2019:
Reclassifications from AOCI
(1)
Gains & losses on cash flow hedges
Long-term debt
For the Years Ended
December 31,
2021
2020
2019
(In millions)
Affected Line Item in Consolidated
Statements of Income
$
$
1 $
1 $
1 $
1 $
2
Interest expense
2 Net of tax
Defined benefit pension and OPEB plans
Prior-service costs
$
(14) $
(34) $
(29) (2)
3
8
8
Income taxes
$
(11) $
(26) $
(21) Net of tax
(1) Amounts in parenthesis represent credits to the Consolidated Statements of Income (Loss) from AOCI.
(2) Prior-service costs are reported within Miscellaneous income, net within Other Income (Expense) on FirstEnergy’s Consolidated
Statements of Income. Components are included in the computation of net periodic cost (credits), see Note 4, "Pension and Other
Postemployment Benefits," for additional details.
4. PENSION AND OTHER POST-EMPLOYMENT BENEFITS
FirstEnergy provides noncontributory qualified defined benefit pension plans that cover substantially all of its employees and
non-qualified pension plans that cover certain employees. The plans provide defined benefits based on years of service and
compensation levels. Under the cash-balance portion of the pension plan (for employees hired on or after January 1, 2014),
FirstEnergy makes contributions to eligible employee retirement accounts based on a pay credit and an interest credit. In
71
addition, FirstEnergy provides a minimum amount of noncontributory life insurance to retired employees in addition to optional
contributory insurance. Health care benefits, which include certain employee contributions, deductibles and co-payments, are
also available upon retirement to certain employees, their dependents and, under certain circumstances, their survivors.
FirstEnergy recognizes the expected cost of providing pension and OPEB to employees and their beneficiaries and covered
dependents from the time employees are hired until they become eligible to receive those benefits. FirstEnergy also has
obligations to former or inactive employees after employment, but before retirement, for disability-related benefits.
FirstEnergy’s pension and OPEB funding policy is based on actuarial computations using the projected unit credit method. On
March 11, 2021, President Biden signed into law the American Rescue Plan Act of 2021, which, among other things, extended
shortfall amortization periods and modification of the interest rate stabilization rules for single-employer plans thereby impacting
funding requirements. As a result, FirstEnergy does not currently expect to have a required contribution to the pension plan
based on various assumptions including annual expected rate of returns for assets of 7.50%. However, FirstEnergy may elect to
contribute to the pension plan voluntarily.
Pension and OPEB costs are affected by employee demographics (including age, compensation levels and employment
periods), the level of contributions made to the plans and earnings on plan assets. Pension and OPEB costs may also be
affected by changes in key assumptions, including anticipated rates of return on plan assets, the discount rates and health care
trend rates used in determining the projected benefit obligations for pension and OPEB costs. FirstEnergy uses a December 31
measurement date for its pension and OPEB plans. The fair value of the plan assets represents the actual market value as of the
measurement date.
Discount Rate - In selecting an assumed discount rate, FirstEnergy considers currently available rates of return on high-quality
fixed income investments expected to be available during the period to maturity of the pension and OPEB obligations. The
assumed rates of return on plan assets consider historical market returns and economic forecasts for the types of investments
held by FirstEnergy’s pension trusts. The long-term rate of return is developed considering the portfolio’s asset allocation
strategy. FirstEnergy utilizes a spot rate approach in the estimation of the components of benefit cost by applying specific spot
rates along the full yield curve to the relevant projected cash flows.
Expected Return on Plan Assets - FirstEnergy’s assumed rate of return on pension plan assets considers historical market
returns and economic forecasts for the types of investments held by the pension trusts. In 2021, FirstEnergy’s qualified pension
and OPEB plan assets experienced gains of $689 million or 7.9%, compared to gains of $1,225 million, or 14.7% in 2020, and
losses of $1,492 million, or 20.2% in 2019 and assumed a 7.50% rate of return on plan assets in 2021, 2020 and 2019, which
generated $688 million, $651 million and $569 million of expected returns on plan assets, respectively. The expected return on
pension and OPEB assets is based on input from investment consultants, including the trusts’ asset allocation targets and the
historical performance of risk-based and fixed income securities. The gains or losses generated as a result of the difference
between expected and actual returns on plan assets is recognized as a pension and OPEB mark-to-market adjustment in the
fourth quarter of each fiscal year and whenever a plan is determined to qualify for remeasurement.
Mortality Rates - During 2021, the Society of Actuaries published new mortality tables that include more current data than the
RP-2014 tables as well as new improvement scales. An analysis of plan mortality data indicated the use of the Pri-2012 mortality
table with projection scale MP-2021, actuarially adjusted to reflect increased mortality rates due to COVID-19 based on mortality
experience reported by the Center for Disease and Control Prevention in 2020 and 2021, was most appropriate and such was
utilized to determine the 2021 benefit cost and obligation as of December 31, 2021, for the FirstEnergy pension and OPEB plans.
The impact of using the Pri-2012 mortality table with projection scale MP-2021 (adjusted by FirstEnergy's actuary for COVID-19
impacts) resulted in a decrease to the projected benefit obligation of approximately $32 million and $2 million for the pension and
OPEB plans, respectively, and was included in the 2021 pension and OPEB mark-to-market adjustment.
Net Periodic Benefit Costs - In addition to service costs, interest on obligations, expected return on plan assets, and prior
service costs, FirstEnergy recognizes in net periodic benefit costs a pension and OPEB mark-to-market adjustment for the
change in the fair value of plan assets and net actuarial gains and losses annually in the fourth quarter of each fiscal year and
whenever a plan is determined to qualify for a remeasurement. Service costs, net of capitalization, are reported within Other
operating expenses on FirstEnergy’s Consolidated Statements of Income. Non-service costs, other than the pension and OPEB
mark-to-market adjustment, which is separately shown, are reported within Miscellaneous income, net, within Other Income
(Expense) on FirstEnergy’s Consolidated Statements of Income.
72
Assumptions Used to Determine Net Periodic
Benefit Cost for the Years Ended December (1)
Service cost weighted-average discount rate (2)
Interest cost weighted-average discount rate (3)
Expected return on plan assets
Pension
OPEB
2021
3.10 % 3.60%/3.24%
2020
2019
4.66 %
2021
3.03 % 3.63%/3.29%
2020
2019
4.67 %
2.58 % 3.27%/2.90%
4.37 %
1.66 % 2.71%/2.30%
3.89 %
7.50 %
7.50 %
7.50 %
7.50 %
7.50 %
7.50 %
Rate of compensation increase
4.10 %
(1)Excludes impact of pension and OPEB mark-to-market adjustment.
(2) Weighted-average discount rates effect from January 1, 2020, through February 26, 2020, were 3.60% and 3.63% for pension and OPEB
service cost, respectively. Discount rates were 3.24% and 3.29% for pension and OPEB service cost, respectively, for the period February 27,
2020 through December 31, 2020.
(3) Weighted-average discount rates in effect from January 1, 2020, through February 26, 2020, were 3.27% and 2.71% for pension and OPEB
interest cost, respectively. Discount rates were 2.90% and 2.30% for pension and OPEB interest cost, respectively, for the period February 27,
2020, through December 31, 2020.
4.10 %
4.10 %
N/A
N/A
N/A
Components of Net Periodic Benefit Costs
(Credits) for the Years Ended December 31,
Service cost
Interest cost
Expected return on plan assets
Amortization of prior service costs (credits) (1)
Special termination costs (2)
One-time termination benefits (3)
Pension & OPEB mark-to-market (4)
Net periodic benefit costs (credits)
Pension
2021
2020
2019
2021
(In millions)
OPEB
2020
2019
$
195 $
194 $
193 $
4 $
4 $
226
287
373
(652)
(618)
(540)
3
—
—
12
—
8
7
14
—
11
(36)
(17)
—
—
(253)
463
656
(129)
15
(33)
(46)
—
—
14
3
22
(29)
(36)
—
—
20
$
(481) $
(20)
(1) 2020 includes the acceleration of approximately $18 million in net credits as a result of the FES Debtors’ emergence during the first quarter of
2020 and is a component of discontinued operations in FirstEnergy’s Consolidated Statements of Income.
(2) Subject to a cap, FirstEnergy agreed to fund a pension enhancement through its pension plan, for voluntary enhanced retirement packages
offered to certain FES employees, as well as offer certain other employee benefits. The costs are a component of discontinued operations in
FirstEnergy’s Consolidated Statements of Income.
(3) Costs represent additional benefits provided to FES and FENOC employees under the approved settlement agreement and are a component
of discontinued operations.
(4) Of the total Pension and OPEB mark-to-market adjustment for 2019, approximately $2 million is included in discontinued operations.
(167) $
703 $
346 $
(46) $
The annual pension and OPEB mark-to-market adjustments, (gains) or losses, for the years ended December 31, 2021, 2020,
and 2019 were $(382) million, $477 million (including $423 million in the first quarter of 2020), and $676 million, respectively. Of
these annual pension and OPEB mark-to-market amounts, approximately $(31) million, $40 million and $47 million were
allocated to the Transmission Companies and certain of FirstEnergy's utilities under forward-looking formula rates, and expected
to be refunded or recovered through formula transmission rates, respectively. The 2021 pension and OPEB mark-to-market
adjustment primarily reflects an approximate 35 bps increase in the discount rate used to measure pension benefit obligations.
Under the approved bankruptcy settlement agreement, upon emergence, FES and FENOC employees ceased earning years of
service under the FirstEnergy pension and OPEB plans. The emergence on February 27, 2020, triggered a remeasurement of
the affected pension and OPEB plans and as a result, FirstEnergy recognized a non-cash, pre-tax pension and OPEB mark-to-
market adjustment of approximately $423 million in the first quarter of 2020. In the fourth quarter 2020, FirstEnergy recognized a
$54 million pension and OPEB mark-to-market adjustment.
73
Obligations and Funded Status - Qualified and Non-Qualified Plans
2021
2020
2021
2020
(In millions)
Pension
OPEB
$
11,935
$
11,050
$
676
$
654
Change in benefit obligation:
Benefit obligation as of January 1
Service cost
Interest cost
Plan participants’ contributions
Plan amendments
Medicare retiree drug subsidy
Actuarial loss (gain)
Benefits paid
Change in fair value of plan assets:
Fair value of plan assets as of January 1
Actual return on plan assets
Company contributions
Plan participants’ contributions
Benefits paid
Benefit obligation as of December 31
$
11,479
$
11,935
$
$
8,968
$
8,395
$
502
$
Fair value of plan assets as of December 31
$
9,020
$
8,968
$
195
226
—
—
—
(280)
(597)
194
287
—
9
—
1,011
(616)
625
24
—
(597)
1,165
24
—
(616)
4
11
4
—
1
(101)
(46)
549
$
64
24
4
(46)
548
—
—
$
$
4
15
4
—
1
41
(43)
676
458
60
23
4
(43)
502
—
—
(1,974)
$
(2,500)
$
(485)
(467)
(2,459)
$
(2,967)
$
(1)
$
(174)
10,927
$
11,376
$
—
$
—
9
$
12
$
(21)
$
(39)
3.02 %
4.10 %
2.57 %
2.67 %
4.10 %
2.57 %
2.84 %
2.45 %
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
5.75%-5.25%
6.0%-5.5%
N/A
N/A
4.5 %
2028
4.5 %
2028
$
$
$
$
Funded Status:
Qualified plan
Non-qualified plans
Funded Status (Net liability as of December 31)
Accumulated benefit obligation
Amounts Recognized in AOCI:
Prior service cost (credit)
Assumptions Used to Determine Benefit Obligations
(as of December 31)
Discount rate
Rate of compensation increase
Cash balance weighted average interest crediting rate
Assumed Health Care Cost Trend Rates
(as of December 31)
Health care cost trend rate assumed (pre/post-Medicare)
Rate to which the cost trend rate is assumed to decline (the ultimate
trend rate)
Year that the rate reaches the ultimate trend rate
74
8 %
35 %
27 %
— %
70 %
9 %
4 %
7 %
10 %
100 %
17 %
23 %
35 %
— %
75 %
5 %
4 %
7 %
9 %
The following tables set forth pension financial assets that are accounted for at fair value by level within the fair value hierarchy.
See Note 8, "Fair Value Measurements," for a description of each level of the fair value hierarchy. There were no significant
transfers between levels during 2021 and 2020.
December 31, 2021
Level 1
Level 2
Level 3
Total
(In millions)
Asset
Allocation
Cash and short-term securities
$
— $
746 $
— $
Public equity
Fixed income
Derivatives
Total (1)
Private - equity and debt funds (2)
Insurance-linked securities (2)
Hedge funds (2)
Real estate funds (2)
Total Investments
2,867
—
20
286
2,453
—
—
—
—
746
3,153
2,453
20
$
2,887 $
3,485 $
— $
6,372
811
320
678
886
$
9,067
(1)
(2)
Excludes $(47) million as of December 31, 2021, of receivables, payables, taxes and accrued income associated with financial instruments
reflected within the fair value table.
Net Asset Value used as a practical expedient to approximate fair value.
December 31, 2020
Level 1
Level 2
Level 3
Total
(In millions)
Asset
Allocation
Cash and short-term securities
$
— $
1,493 $
— $
Public equity
Fixed income
Derivatives
Total (1)
Private - equity and debt funds (2)
Insurance-linked securities (2)
Hedge funds (3)
Real estate funds (2)
Total Investments
1,903
—
(13)
162
3,059
—
—
—
—
1,493
2,065
3,059
(13)
$
1,890 $
4,714 $
— $
6,604
465
323
645
815
$
8,852
100 %
(1)
(2)
Excludes $116 million as of December 31, 2020, of receivables, payables, taxes and accrued income associated with financial instruments
reflected within the fair value table.
Net Asset Value used as a practical expedient to approximate fair value.
As of December 31, 2021, and 2020, the OPEB trust investments measured at fair value were as follows:
December 31, 2021
Level 1
Level 2
Level 3
Total
Asset
Allocation
(In millions)
Cash and short-term securities
$
— $
95 $
— $
Public equity
Fixed income
Total
278
—
—
175
—
—
$
278 $
270 $
— $
95
278
175
548
17 %
51 %
32 %
100 %
75
Cash and short-term securities
Public equity
December 31, 2020
Level 1
Level 2
Level 3
Total
Asset
Allocation
(In millions)
$
— $
84 $
— $
283
—
—
84
283
17 %
55 %
Fixed income:
Total (1)
(1) Excludes $(10) million as of December 31, 2020, of receivables, payables, taxes and accrued income associated with financial instruments
reflected within the fair value table.
283 $
229 $
— $
100 %
28 %
512
145
145
—
—
$
FirstEnergy follows a total return investment approach using a mix of equities, fixed income and other available investments
while taking into account the pension plan liabilities to optimize the long-term return on plan assets for a prudent level of risk.
Risk tolerance is established through careful consideration of plan liabilities, plan funded status and corporate financial condition.
The investment portfolio contains a diversified blend of equity and fixed-income investments. Equity investments are diversified
across U.S. and non-U.S. stocks, as well as growth, value, and small and large capitalization funds. Other assets such as real
estate and private equity are used to enhance long-term returns while improving portfolio diversification. Derivatives may be used
to gain market exposure in an efficient and timely manner; however, derivatives are not used to leverage the portfolio beyond the
market value of the underlying investments. Investment risk is measured and monitored on a continuing basis through periodic
investment portfolio reviews, annual liability measurements and periodic asset/liability studies.
FirstEnergy’s target asset allocations for its pension and OPEB trust portfolios for 2021 and 2020 are shown in the following
table:
Target Asset Allocations
2021
2020
Equities
Fixed income
Hedge funds
Real estate
Alternative investments
Cash and short-term securities
38 %
30 %
8 %
10 %
8 %
6 %
38 %
30 %
8 %
10 %
8 %
6 %
100 %
100 %
Taking into account estimated employee future service, FirstEnergy expects to make the following benefit payments from plan
assets and other payments, net of participant contributions:
2022
2023
2024
2025
2026
Years 2027-2030
(1)
(1)
(1)
—
—
(2)
Pension
OPEB
Subsidy
Receipts
Benefit
Payments
(In millions)
$
566 $
44 $
41
39
38
37
164
575
581
590
598
3,075
76
5. STOCK-BASED COMPENSATION PLANS
FirstEnergy grants stock-based awards through the ICP 2020, primarily in the form of restricted stock and performance-based
restricted stock units. There are also awards currently outstanding issued through the ICP 2015 primarily in the form of restricted
stock and performance-based restricted stock units. The ICP 2020 and ICP 2015 include shareholder authorization to each issue
10 million shares of common stock or their equivalent. As of December 31, 2021, approximately 12.7 million shares were
available for future grants under the ICP 2020 assuming maximum performance metrics are achieved for the outstanding cycles
of restricted stock units. No shares are available for future grants under ICP 2015. Shares not issued due to forfeitures or
cancellations originally granted through the ICP 2015 may be added back to the ICP 2020. Shares granted under the ICP 2020
and ICP 2015 are issued from authorized but unissued common stock. Vesting periods for stock-based awards range from two to
ten years, with the majority of awards having a vesting period of three years. FirstEnergy also issues stock through its 401(k)
Savings Plan, EDCP, and DCPD. Currently, FirstEnergy records the compensation costs for stock-based compensation awards
that will be paid in stock over the vesting period based on the fair value on the grant date. FirstEnergy accounts for forfeitures as
they occur.
FirstEnergy adjusts the compensation costs for stock-based compensation awards that will be paid in cash based on changes in
the fair value of the award as of each reporting date. FirstEnergy records the actual tax benefit realized from tax deductions
when awards are exercised or settled. Actual income tax benefits realized during the years ended December 31, 2021, 2020 and
2019, were $10 million, $20 million and $24 million, respectively. The income tax effects of awards are recognized in the income
statement when the awards vest, are settled or are forfeited.
Stock-based compensation costs and the amount of stock-based compensation costs capitalized related to FirstEnergy plans for
the years ended December 31, 2021, 2020 and 2019, are included in the following tables:
Stock-based Compensation Plan
Restricted Stock Units
Restricted Stock
401(k) Savings Plan
EDCP & DCPD
Total
Stock-based compensation costs capitalized
For the Years Ended December 31,
2021
2020
(In millions)
2019
$
40 $
22 $
2
35
13
$
$
90 $
47 $
1
33
(5)
51 $
26 $
73
1
33
9
116
54
Income tax benefits associated with stock-based compensation plan expense were $5 million, $3 million and $10 million for the
years ended December 31, 2021, 2020 and 2019, respectively.
Restricted Stock Units
Beginning with the performance-based restricted stock units granted in 2015, two-thirds of each award will be paid in stock and
one-third will be paid in cash. Restricted stock units payable in stock provide the participant the right to receive, at the end of the
period of restriction, a number of shares of common stock equal to the number of stock units set forth in the agreement, subject
to adjustment based on FirstEnergy's performance relative to financial and operational performance targets applicable to each
award. The grant date fair value of the stock portion of the restricted stock unit award is measured based on the average of the
high and low prices of FE common stock on the date of grant. Beginning with awards granted in 2018, restricted stock units
include a performance metric consisting of a relative total shareholder return modifier utilizing the S&P 500 Utility Index as a
comparator group. The estimated grant date fair value for these awards is calculated using the Monte Carlo simulation method.
Restricted stock units payable in cash provide the participant the right to receive cash based on the number of stock units set
forth in the agreement and value of the equivalent number of shares of FE common stock as of the vesting date. The cash
portion of the restricted stock unit award is considered a liability award, which is remeasured each period based on FE's stock
price and projected performance adjustments. The liability recorded for the portion of performance-based restricted stock units
payable in cash in the future as of December 31, 2021, was $24 million. During 2021, approximately $11 million was paid in
relation to the cash portion of restricted stock unit obligations that vested in 2021.
The vesting period for the performance-based restricted stock unit awards granted in 2019, 2020 and 2021, were each three
years. Dividend equivalents are received on the restricted stock units and are reinvested in additional restricted stock units and
subject to the same performance conditions as the underlying award.
77
Restricted stock unit activity for the year ended December 31, 2021, was as follows:
Restricted Stock Unit Activity
Nonvested as of January 1, 2021
Granted in 2021
Forfeited in 2021
Vested in 2021(1)
Nonvested as of December 31, 2021
Shares
(in millions)
Weighted-Average
Grant Date Fair Value
(per share)
$
1.8
1.3
(0.3)
(1.0)
1.8
$
40.25
35.50
40.08
33.73
41.89
(1) Excludes dividend equivalents of approximately 130 thousand shares earned during vesting period.
The weighted-average fair value of awards granted in 2021, 2020 and 2019 was $35.50, $44.42 and $41.23 per share,
respectively. For the years ended December 31, 2021, 2020, and 2019, the fair value of restricted stock units vested was
$34 million, $80 million, and $91 million, respectively. As of December 31, 2021, there was approximately $29 million of total
unrecognized compensation cost related to nonvested share-based compensation arrangements granted for restricted stock
units, which is expected to be recognized over a period of approximately three years.
Restricted Stock
Certain employees receive awards of FE restricted stock (as opposed to "units" with the right to receive shares at the end of the
restriction period) subject to restrictions that lapse over a defined period of time or upon achieving performance results. The fair
value of restricted stock is measured based on the average of the high and low prices of FE common stock on the date of grant.
Dividends are received on the restricted stock and are reinvested in additional shares of restricted stock, subject to the vesting
conditions of the underlying award. Restricted stock activity for the year ended December 31, 2021, was not material.
401(k) Savings Plan
In 2021 and 2020, approximately 1 million shares of FE common stock, respectively, were issued and contributed to participants'
accounts.
EDCP
Under the EDCP, certain employees can defer a portion of their compensation, including base salary, annual incentive awards
and/or long-term incentive awards, into unfunded accounts. Annual incentive and long-term incentive awards may be deferred in
FE stock accounts. Base salary and annual incentive awards may be deferred into a retirement cash account which earns
interest. Dividends are calculated quarterly on stock units outstanding and are credited in the form of additional stock units. The
form of payout as stock or cash vary depending upon the form of the award, the duration of the deferral and other
factors. Awards deferred into a retirement stock account will pay out in cash upon separation from service, death or disability.
Interest accrues on the cash allocated to the retirement cash account and the balance will pay out in cash over a time period as
elected by the participant.
DCPD
Under the DCPD, members of the FE Board can elect to defer all or a portion of their equity retainers to a deferred stock account
and their cash retainers to deferred stock or deferred cash accounts. The net liability recognized for DCPD of approximately
$9 million and $7 million as of December 31, 2021 and 2020, respectively, is included in “Retirement benefits,” on the
Consolidated Balance Sheets.
6. TAXES
FirstEnergy records income taxes in accordance with the liability method of accounting. Deferred income taxes reflect the net tax
effect of temporary differences between the carrying amounts of assets and liabilities for financial reporting purposes and the
amounts recognized for tax purposes. Investment tax credits, which were deferred when utilized, are being amortized over the
recovery period of the related property. Deferred income tax liabilities related to temporary tax and accounting basis differences
and tax credit carryforward items are recognized at the statutory income tax rates in effect when the liabilities are expected to be
paid. Deferred tax assets are recognized based on income tax rates expected to be in effect when they are settled.
FE and its subsidiaries are party to an intercompany income tax allocation agreement that provides for the allocation of
consolidated tax liabilities. Net tax benefits attributable to FE, excluding any tax benefits derived from certain interest expense,
are generally reallocated to the subsidiaries of FE that have taxable income. That allocation is accounted for as a capital
contribution to the company receiving the tax benefit.
78
On April 9, 2021, West Virginia enacted legislation changing the state’s corporate income tax apportionment rules, including
adopting a single sales factor formula and market-based sourcing for sales of services and intangibles, effective for taxable years
beginning on or after January 1, 2022. Enactment of this law triggered a remeasurement of state deferred income taxes for
entities included in FirstEnergy’s West Virginia combined unitary return, resulting in a net impact of approximately $9 million in
additional tax expense in 2021.
INCOME TAXES(1)
Currently payable (receivable)-
Federal (2)
State
Deferred, net-
Federal(3)
State(4)
For the Years Ended December 31,
2021
2020
(In millions)
2019
$
2 $
(14) $
21
23
174
127
301
21
7
171
(38)
133
(14)
126 $
(16)
24
8
150
60
210
(5)
213
Investment tax credit amortization
Total income taxes
$
(4)
320 $
(1)
(2)
(3)
(4)
Income Taxes on Income from Continuing Operations.
Excludes $2 million of federal tax benefit and $6 million of federal tax expense associated with discontinued
operations for the years ended December 31, 2021 and 2020 respectively.
Excludes $46 million, $66 million and $9 million of federal tax benefits associated with discontinued operations
for the years ended December 31, 2021, 2020 and 2019, respectively.
Excludes $1 million and $4 million of state tax expense associated with discontinued operations for the years
ended December 31, 2020 and 2019, respectively.
FirstEnergy tax rates are affected by permanent items, such as AFUDC equity and other flow-through items, as well as discrete
items that may occur in any given period but are not consistent from period to period. The following tables provide a
reconciliation of federal income tax expense (benefit) at the federal statutory rate to the total income taxes (benefits) for the years
ended December 31, 2021, 2020 and 2019:
For the Years Ended December 31,
2021
2020
(In millions)
2019
Income from Continuing Operations, before income taxes
Federal income tax expense at statutory rate (21%)
Increases (reductions) in taxes resulting from-
State income taxes, net of federal tax benefit
AFUDC equity and other flow-through
Amortization of investment tax credits
Federal tax credits claimed
Nondeductible DPA monetary penalty
Excess deferred tax amortization due to the Tax Act
TMI-2 reversal of tax regulatory liabilities
Uncertain tax positions
Valuation allowances
Other, net
Total income taxes
Effective income tax rate
$
$
1,559
327
122
(29)
(4)
(34)
52
(54)
—
(82)
17
5
$
$
1,129
237
$
$
1,117
235
75
(38)
(14)
—
—
(56)
(40)
(1)
(49)
12
126
96
(36)
(5)
—
—
(74)
—
(11)
5
3
$
213
$
320
$
20.5 %
11.2 %
19.1 %
79
FirstEnergy's effective tax rate on continuing operations for 2021 and 2020 was 20.5% and 11.2%, respectively. The increase in
effective tax rate was primarily due to:
•
•
•
•
•
•
•
The non-deductibility of the DPA monetary penalty;
The absence of a $52 million benefit for reduction in valuation allowances in 2020 from the recognition of deferred gains
on prior intercompany generation asset transfers triggered by the FES Debtors’ emergence from bankruptcy and
deconsolidation from FirstEnergy’s consolidated federal income tax group;
Lower amortization of investment tax credits due to the absence of a $10 million benefit from accelerated amortization
of certain investment credits in 2020;
The absence of a $40 million benefit related to reversals of certain tax regulatory liabilities resulting from the transfer of
TMI-2 in 2020;
Additional tax expense of $9 million as a result of the West Virginia legislation that changed income tax apportionment
rules discussed above;
Partially offset by a net $81 million increase in uncertain tax position benefits primarily related to reserves on the
worthless stock deduction, nondeductible interest under Section 163(j), and certain federal tax credits, discussed below;
and
A $34 million benefit in federal tax credits claimed on FirstEnergy’s federal income tax return in 2021.
Accumulated deferred income taxes as of December 31, 2021 and 2020, are as follows:
Property basis differences
Pension and OPEB
AROs
Regulatory asset/liability
Deferred compensation
Loss carryforwards and tax credits
Valuation reserve
All other
Net deferred income tax liability
As of December 31,
2020
2021
(In millions)
5,670 $
(570)
(21)
322
(155)
(2,040)
484
(253)
3,437 $
5,396
(769)
(28)
440
(165)
(1,995)
496
(280)
3,095
$
$
FirstEnergy has recorded as deferred income tax assets the effect of Federal NOLs and tax credits that will more likely than not
be realized through future operations and through the reversal of existing temporary differences. As of December 31, 2021,
FirstEnergy's loss carryforwards primarily consisted of $6.9 billion ($1.5 billion, net of tax) of Federal NOL carryforwards that will
begin to expire in 2031.
The table below summarizes pre-tax NOL carryforwards and their respective anticipated expirations for state and local income
tax purposes of approximately $11.9 billion ($544 million, net of tax) for FirstEnergy, of which approximately $2.7 billion ($136
million, net of tax) is expected to be utilized based on current estimates and assumptions. The ultimate utilization of these NOLs
may be impacted by statutory limitations on the use of NOLs imposed by state and local tax jurisdictions, changes in statutory tax
rates, and changes in business which, among other things, impact both future profitability and the manner in which future taxable
income is apportioned to various state and local tax jurisdictions.
Expiration Period
2022-2026
2027-2031
2032-2036
2037-2041
Indefinite
State
Local
(In millions)
$
2,603 $
3,783
1,390
992
959
2,157
—
—
—
—
$
8,101 $
3,783
80
The following table summarizes the changes in valuation allowances on federal, state and local DTAs related to disallowed
interest and certain employee remuneration, in addition to state and local NOLs discussed above for the years ended December
31, 2021, 2020 and 2019:
(In millions)
Beginning of year balance
Charged to income
Charged to other accounts
Write-offs
End of year balance
2021
2020
2019
$
496 $
(12)
—
—
441 $
394
55
—
—
47
—
—
$
484 $
496 $
441
FirstEnergy accounts for uncertainty in income taxes recognized in its financial statements. A recognition threshold and
measurement attribute are utilized for financial statement recognition and measurement of tax positions taken or expected to be
taken on the tax return. As of December 31, 2021 and 2020, FirstEnergy's total unrecognized income tax benefits were
approximately $47 million and $139 million, respectively. The $92 million net decrease in unrecognized income tax benefits is
primarily due to:
•
•
•
•
Decreases of $68 million for reserves related to the worthless stock deduction (see Note 14, "Discontinued Operations,"
for further discussion) and $29 million for reserves attributable to nondeductible interest under Section 163(j), both of
which were effectively settled with federal taxing authorities;
Decrease of $7 million to the reserve due to the remeasurement of certain positions for the change in West Virginia
deferred taxes resulting from a state law change discussed above and $1 million due to other state tax rate changes;
Decrease of $2 million due to the lapse in statue in certain state taxing jurisdictions;
Partially offset by an increase of $15 million for reserves related to certain federal tax credits claimed on FirstEnergy's
federal income tax return in 2021.
If ultimately recognized in future years, approximately $39 million of unrecognized income tax benefits would impact the effective
tax rate.
As of December 31, 2021, it is reasonably possible that approximately $31 million of unrecognized tax benefits may be resolved
during 2022 as a result of settlements with taxing authorities or the statute of limitations expiring, of which $24 million would
ultimately affect FirstEnergy's effective tax rate.
The following table summarizes the changes in unrecognized tax positions for the years ended December 31, 2021, 2020 and
2019:
Balance, January 1, 2019
Current year increases
Prior year decreases
Decrease for lapse in statute
Balance, December 31, 2019
Current year increases
Prior year decreases
Decrease for lapse in statute
Effectively settled with taxing authorities
Balance, December 31, 2020
Current year increases
Prior years decreases
Effectively settled with taxing authorities
Decrease for lapse in statute
Balance, December 31, 2021
(In millions)
$
$
$
$
158
22
(12)
(4)
164
7
(28)
(2)
(2)
139
15
(8)
(97)
(2)
47
FirstEnergy recognizes interest expense or income and penalties related to uncertain tax positions in income taxes by applying
the applicable statutory interest rate to the difference between the tax position recognized and the amount previously taken, or
expected to be taken, on the tax return. FirstEnergy includes net interest and penalties in the provision for income taxes.
81
FirstEnergy's recognition of net interest associated with unrecognized tax benefits in 2021, 2020 and 2019, was not material. For
the years ended December 31, 2021 and 2020, the cumulative net interest payable recorded by FirstEnergy was not material.
IRS review of FirstEnergy’s federal income tax returns is complete through the 2020 tax year with no pending adjustments.
FirstEnergy’s tax returns for some state jurisdictions are open from tax years 2009 to 2020.
General Taxes
General tax expense for the years ended December 31, 2021, 2020 and 2019, recognized in continuing operations is
summarized as follows:
KWH excise
State gross receipts
Real and personal property
Social security and unemployment
Other
Total general taxes
7. LEASES
For the Years Ended December 31,
2021
2020
(In millions)
2019
$
189 $
183 $
190
571
103
20
182
541
112
28
191
185
504
100
28
$
1,073 $
1,046 $
1,008
FirstEnergy primarily leases vehicles as well as building space, office equipment, and other property and equipment under
cancellable and non-cancelable leases. FirstEnergy does not have any material leases in which it is the lessor.
FirstEnergy accounts for leases under, "Leases (Topic 842)". Leases with an initial term of 12 months or less are recognized as
lease expense on a straight-line basis over the lease term and not recorded on the balance sheet. Most leases include one or
more options to renew, with renewal terms that can extend the lease term from 1 to 40 years, and certain leases include options
to terminate. The exercise of lease renewal options is at FirstEnergy’s sole discretion. Renewal options are included within the
lease liability if they are reasonably certain based on various factors relative to the contract. Certain leases also include options
to purchase the leased property. The depreciable life of leased assets and leasehold improvements are limited by the expected
lease term unless there is a transfer of title or purchase option reasonably certain of exercise. FirstEnergy’s lease agreements do
not contain any material restrictive covenants. FirstEnergy has elected a policy to not separate lease components from non-lease
components for all asset classes.
For vehicles leased under certain master lease agreements, the lessor is guaranteed a residual value up to a stated percentage
of the equipment cost at the end of the lease term. If the actual fair value of the leased equipment is below the guaranteed
residual value at the end of the lease term, FirstEnergy is committed to pay the difference in the actual fair value and the residual
value guarantee. FirstEnergy does not believe it is probable that it will be required to pay anything pertaining to the residual value
guarantee, and the lease liabilities and right-of-use assets are measured accordingly.
Finance leases for assets used in regulated operations are recognized in FirstEnergy’s Consolidated Statements of Income such
that amortization of the right-of-use asset and interest on lease liabilities equals the expense allowed for ratemaking purposes.
Finance leases for regulated and non-regulated operations are accounted for as if the assets were owned and financed, with
associated expense recognized in Interest expense and Provision for depreciation on FirstEnergy’s Consolidated Statements of
Income, while all operating lease expenses are recognized in Other operating expense. The components of lease expense were
as follows:
(In millions)
Operating lease costs (1)
Finance lease costs:
For the Year Ended December 31, 2021
Vehicles
Buildings
Other
Total
$
44 $
9 $
18 $
Amortization of right-of-use assets
Interest on lease liabilities
Total finance lease cost
12
1
13
1
3
4
1
—
1
Total lease cost
$
57 $
13 $
19 $
(1) Includes $21 million of short-term lease costs.
71
14
4
18
89
82
(In millions)
Operating lease costs (1)
Finance lease costs:
For the Year Ended December 31, 2020
Vehicles
Buildings
Other
Total
$
35 $
8 $
17 $
Amortization of right-of-use assets
Interest on lease liabilities
Total finance lease cost
14
2
16
—
3
3
1
—
1
Total lease cost
$
51 $
11 $
18 $
(1) Includes $17 million of short-term lease costs.
(In millions)
Operating lease costs (1)
Finance lease costs:
For the Year Ended December 31, 2019
Vehicles
Buildings
Other
Total
$
28 $
9 $
12 $
Amortization of right-of-use assets
Interest on lease liabilities
Total finance lease cost
15
3
18
1
3
4
1
—
1
Total lease cost
$
(1) Includes $13 million of short-term lease costs.
46 $
13 $
13 $
Supplemental cash flow information related to leases was as follows:
60
15
5
20
80
49
17
6
23
72
(In millions)
Cash paid for amounts included in the measurement of lease liabilities:
For the Years Ended December 31,
2021
2020
2019
Operating cash flows from operating leases
$
64 $
44 $
Operating cash flows from finance leases
Finance cash flows from finance leases
4
13
4
15
Right-of-use assets obtained in exchange for lease obligations:
Operating leases
Finance leases
$
60 $
5
67 $
—
29
5
25
83
3
Lease terms and discount rates were as follows:
Weighted-average remaining lease terms (years)
Operating leases
Finance leases
Weighted-average discount rate (1)
Operating leases
Finance leases
As of December 31,
2021
2020
2019
7.97
8.12
8.55
7.74
9.42
4.62
4.16 %
12.22 %
4.21 %
11.58 %
4.51 %
10.45 %
(1) When an implicit rate is not readily determinable, an incremental borrowing rate is utilized, determining the present value of lease payments.
The rate is determined based on expected term and information available at the commencement date.
83
Supplemental balance sheet information related to leases was as follows:
(In millions)
Financial Statement Line Item
2021
2020
As of December 31,
Assets
Operating lease (1)
Finance lease (2)
Total leased assets
Liabilities
Current:
Operating
Finance
Noncurrent:
Operating
Finance
Deferred charges and other assets $
Property, plant and equipment
$
Other current liabilities $
Currently payable long-term debt
Other noncurrent liabilities
Long-term debt and other long-term obligations
279 $
48
327 $
39 $
13
271
23
265
57
322
42
14
263
31
Total leased liabilities
350
(1) Operating lease assets are recorded net of accumulated amortization of $79 million and $51 million as of December 31, 2021 and 2020,
respectively.
(2) Finance lease assets are recorded net of accumulated amortization of $95 million and $96 million as of December 31, 2021 and 2020,
respectively.
346 $
$
Maturities of lease liabilities as of December 31, 2021, were as follows:
(In millions)
2022
2023
2024
2025
2026
Thereafter
Total lease payments (1)
Less imputed interest
Operating Leases
Finance Leases
Total
$
54 $
16 $
54
48
45
41
133
375
65
9
5
5
5
8
48
12
Total net present value
$
310 $
36 $
(1) Operating lease payments for certain leases are offset by sublease receipts of $10 million over 11 years.
70
63
53
50
46
141
423
77
346
As of December 31, 2021, additional operating leases agreements, primarily for vehicles, that have not yet commenced are $5
million. These leases are expected to commence within the next 18 months with lease terms of 2 to 10 years.
8. FAIR VALUE MEASUREMENTS
RECURRING FAIR VALUE MEASUREMENTS
Authoritative accounting guidance establishes a fair value hierarchy that prioritizes the inputs used to measure fair value. This
hierarchy gives the highest priority to Level 1 measurements and the lowest priority to Level 3 measurements. The three levels of
the fair value hierarchy and a description of the valuation techniques are as follows:
Level 1
- Quoted prices for identical instruments in active market
Level 2
- Quoted prices for similar instruments in active market
- Quoted prices for identical or similar instruments in markets that are not active
- Model-derived valuations for which all significant inputs are observable market data
Models are primarily industry-standard models that consider various assumptions, including quoted forward
prices for commodities, time value, volatility factors and current market and contractual prices for the underlying
instruments, as well as other relevant economic measures.
84
Level 3
- Valuation inputs are unobservable and significant to the fair value measurement
FirstEnergy produces a long-term power and capacity price forecast annually with periodic updates as market
conditions change. When underlying prices are not observable, prices from the long-term price forecast are used
to measure fair value.
FTRs are financial instruments that entitle the holder to a stream of revenues (or charges) based on the hourly
day-ahead congestion price differences across transmission paths. FTRs are acquired by FirstEnergy in the
annual, monthly and long-term PJM auctions and are initially recorded using the auction clearing price less cost.
After initial recognition, FTRs' carrying values are periodically adjusted to fair value using a mark-to-model
methodology, which approximates market. The primary inputs into the model, which are generally less
observable than objective sources, are the most recent PJM auction clearing prices and the FTRs' remaining
hours. The model calculates the fair value by multiplying the most recent auction clearing price by the remaining
FTR hours less the prorated FTR cost. Significant increases or decreases in inputs in isolation may have resulted
in a higher or lower fair value measurement.
NUG contracts represent PPAs with third-party non-utility generators that are transacted to satisfy certain
obligations under PURPA. NUG contract carrying values are recorded at fair value and adjusted periodically
using a mark-to-model methodology, which approximates market. The primary unobservable inputs into the
model are regional power prices and generation MWH. Pricing for the NUG contracts is a combination of market
prices for the current year and next two years based on observable data and internal models using historical
trends and market data for the remaining years under contract. The internal models use forecasted energy
purchase prices as an input when prices are not defined by the contract. Forecasted market prices are based on
Intercontinental Exchange, Inc. quotes and management assumptions. Generation MWH reflects data provided
by contractual arrangements and historical trends. The model calculates the fair value by multiplying the prices
by the generation MWH. Significant increases or decreases in inputs in isolation may have resulted in a higher or
lower fair value measurement.
For investments reported at NAV where there is no readily determinable fair value, a practical expedient is available that allows
the NAV to approximate fair value. Investments that use NAV as a practical expedient are excluded from the requirement to be
categorized within the fair value hierarchy tables. Instead, these investments are reported outside of the fair value hierarchy
tables to assist in the reconciliation of investment balances reported in the tables to the balance sheet. FirstEnergy has elected
the NAV practical expedient for investments in private equity funds, insurance-linked securities, hedge funds (absolute return)
and real estate funds held within the pension plan. See Note 4, "Pension And Other Post-Employment Benefits" for the pension
financial assets accounted for at fair value by level within the fair value hierarchy.
FirstEnergy primarily applies the market approach for recurring fair value measurements using the best information available.
Accordingly, FirstEnergy maximizes the use of observable inputs and minimizes the use of unobservable inputs. There were no
changes in valuation methodologies used as of December 31, 2021, from those used as of December 31, 2020. The
determination of the fair value measures takes into consideration various factors, including but not limited to, nonperformance
risk, counterparty credit risk and the impact of credit enhancements (such as cash deposits, LOCs and priority interests). The
impact of these forms of risk was not significant to the fair value measurements.
85
The following tables set forth the recurring assets and liabilities that are accounted for at fair value by level within the fair value
hierarchy:
Assets
Derivative assets FTRs(1)
Equity securities
U.S. state debt securities
Cash, cash equivalents and restricted cash(2)
Other(3)
December 31, 2021
December 31, 2020
Level 1
Level 2
Level 3
Total
Level 1
Level 2
Level 3
Total
(In millions)
$ — $
— $
9 $
9 $ — $
— $
3 $
2
—
1,511
—
—
273
—
42
—
—
—
—
2
273
2
—
1,511
1,801
42
—
—
276
—
41
—
—
—
—
3
2
276
1,801
41
Total assets
$ 1,513 $
315 $
9 $ 1,837 $ 1,803 $
317 $
3 $ 2,123
Liabilities
Derivative liabilities FTRs(1)
Total liabilities
Net assets (liabilities)
(1)
(4)
$ — $
$ — $
— $
— $
(1) $
(1) $
(1) $ — $
(1) $ — $
— $
— $
— $
— $
—
—
$ 1,513 $
315 $
8 $ 1,836 $ 1,803 $
317 $
3 $ 2,123
(2)
(3)
(4)
Contracts are subject to regulatory accounting treatment and changes in market values do not impact earnings.
Restricted cash of $49 million and $67 million as of December 31, 2021 and 2020 respectively, primarily relates to cash collected from
JCP&L, MP, PE and the Ohio Companies' customers that is specifically used to service debt of their respective funding companies.
Primarily consists of short-term investments.
Excludes $1 million as of December 31, 2020, of receivables, payables, taxes and accrued income associated with financial instruments
reflected within the fair value table.
Rollforward of Level 3 Measurements
The following table provides a reconciliation of changes in the fair value of NUG contracts and FTRs that are classified as Level
3 in the fair value hierarchy for the years ended December 31, 2021 and 2020:
NUG Contracts(1)
FTRs(1)
Derivative
Assets
Derivative
Liabilities
Derivative
Assets
Net
(In millions)
Derivative
Liabilities
Net
$
— $
(16) $
(16) $
4 $
(1) $
—
—
—
(3)
—
19
(3)
—
19
(3)
7
(5)
—
(2)
3
$
— $
— $
— $
3 $
— $
—
—
—
—
—
—
—
—
—
7
5
(6)
—
(2)
1
3
(3)
5
(2)
3
7
3
(5)
January 1, 2020 Balance
Unrealized gain (loss)
Purchases
Settlements
December 31, 2020 Balance
Unrealized gain (loss)
Purchases
Settlements
December 31, 2021 Balance
(1) Contracts are subject to regulatory accounting treatment and changes in market values do not impact earnings.
— $
— $
(1) $
8
— $
9 $
$
Level 3 Quantitative Information
The following table provides quantitative information for FTRs contracts that are classified as Level 3 in the fair value hierarchy
for the year ended December 31, 2021:
Fair Value, Net
(In millions)
FTRs
$
8
Valuation
Technique
Model
Significant Input
RTO auction clearing prices
Range
Weighted
Average
$1.10 to
$4.60
$1.80
Units
Dollars/MWH
INVESTMENTS
All temporary cash investments purchased with an initial maturity of three months or less are reported as cash equivalents on the
Consolidated Balance Sheets at cost, which approximates their fair market value. Investments other than cash and cash
equivalents include AFS debt securities and other investments. FirstEnergy has no debt securities held for trading purposes.
86
Generally, unrealized gains and losses on equity securities are recognized in income whereas unrealized gains and losses on
AFS debt securities are recognized in AOCI. However, the JCP&L spent nuclear fuel disposal trusts are subject to regulatory
accounting with all gains and losses on equity and AFS debt securities offset against regulatory assets. On October 15, 2019,
JCP&L, ME, PN and GPUN executed an asset purchase and sale agreement with TMI-2 Solutions, LLC, a subsidiary of
EnergySolutions, LLC, concerning the transfer and dismantlement of TMI-2. With the receipt of all required regulatory approvals,
the transaction was consummated, including the transfer of external trusts for the decommissioning and environmental
remediation of TMI-2, on December 18, 2020.
Spent Nuclear Fuel Disposal Trusts
JCP&L holds debt securities within the spent nuclear fuel disposal trust, which are classified as AFS securities, recognized at fair
market value. The trust is intended for funding spent nuclear fuel disposal fees to the DOE associated with the previously owned
Oyster Creek and TMI-1 nuclear power plants.
The following table summarizes the amortized cost basis, unrealized gains, unrealized losses and fair values of investments held
in nuclear fuel disposal trusts as of December 31, 2021 and 2020:
December 31, 2021(1)
December 31, 2020(2)
Cost
Basis
Unrealized
Gains
Unrealized
Losses
Fair Value
Cost
Basis
Unrealized
Gains
Unrealized
Losses
Fair Value
(In millions)
Debt securities
$
280 $
2 $
(9) $
273 $
275 $
7 $
(6) $
276
(1)
(2)
Excludes short-term cash investments of $11 million.
Excludes short-term cash investments of $9 million.
Proceeds from the sale of investments in AFS debt securities, realized gains and losses on those sales and interest and dividend
income for the years ended December 31, 2021, 2020 and 2019, were as follows:
For the Years Ended December 31,
2020(1)
(In millions)
2019(1)
2021
Sale Proceeds
Realized Gains
Realized Losses
Interest and Dividend Income
$
48 $
186 $
1,637
—
(3)
11
12
(8)
22
98
(31)
38
(1) Includes amounts associated with NDTs that were previously held by JCP&L, ME, and PN. See above for
additional information.
Other Investments
Other investments include employee benefit trusts, which are primarily invested in corporate-owned life insurance policies, and
equity method investments. Other investments were $371 million and $322 million as of December 31, 2021 and 2020,
respectively, and are excluded from the amounts reported above.
87
LONG-TERM DEBT AND OTHER LONG-TERM OBLIGATIONS
All borrowings with initial maturities of less than one year are defined as short-term financial instruments under GAAP and are
reported as Short-term borrowings on the Consolidated Balance Sheets at cost. Since these borrowings are short-term in nature,
FirstEnergy believes that their costs approximate their fair market value. The following table provides the approximate fair value
and related carrying amounts of long-term debt, which excludes finance lease obligations and net unamortized debt issuance
costs, unamortized fair value adjustments, premiums and discounts as of December 31, 2021 and 2020:
As of December 31,
2021
2020
(In millions)
Carrying Value
Fair Value
$
23,946 $
27,043
22,377
25,465
The fair values of long-term debt and other long-term obligations reflect the present value of the cash outflows relating to those
securities based on the current call price, the yield to maturity or the yield to call, as deemed appropriate at the end of each
respective period. The yields assumed were based on securities with similar characteristics offered by corporations with credit
ratings similar to those of FirstEnergy. FirstEnergy classified short-term borrowings, long-term debt and other long-term
obligations as Level 2 in the fair value hierarchy as of December 31, 2021 and 2020.
See Note 9, "Capitalization," for further information on long-term debt issued during the twelve months ended December 31,
2021.
9. CAPITALIZATION
COMMON STOCK
Retained Earnings and Dividends
As of December 31, 2021, FirstEnergy had an accumulated deficit of $1.6 billion. Dividends declared in 2021 and 2020 totaled
$1.56 per share in each period. Dividends of $0.39 per share were paid in the first, second, third and fourth quarters in 2021 and
2020, respectively. On December 21, 2021, the FE Board declared a quarterly dividend of $0.39 per share to be paid from OPIC
in the first quarter of 2022. The amount and timing of all dividend declarations are subject to the discretion of the FE Board and
its consideration of business conditions, results of operations, financial condition, risks and uncertainties of the government
investigations, and other factors.
In addition to paying dividends from retained earnings, the Ohio Companies, Penn, JCP&L, ME and PN have authorization from
FERC to pay cash dividends to FE from paid-in capital accounts, as long as their FERC-defined equity-to-total-capitalization ratio
remains above 35%. In addition, AGC has authorization from FERC to pay cash dividends to its parent, MP, from paid-in capital
accounts, as long as its FERC-defined equity-to-total-capitalization ratio remains above 45%. The articles of incorporation,
indentures, regulatory limitations, FET P&SA, and various other agreements, including those relating to the long-term debt of
certain FirstEnergy subsidiaries contain provisions that could further restrict the payment of dividends on their common stock.
None of these provisions materially restricted FirstEnergy subsidiaries’ abilities to pay cash dividends to FE as of December 31,
2021.
Common Stock Issuance
FE issued approximately 1 million shares of common stock in 2021, 2 million shares of common stock in 2020 and 3 million
shares of common stock in 2019 to registered shareholders and its directors and the employees of its subsidiaries under its
Stock Investment Plan and certain share-based benefit plans.
On November 6, 2021, FE entered into a Common Stock Purchase Agreement with BIP Securities II-B L.P., an affiliate of
Blackstone Infrastructure Partners L.P., for the private placement of 25,588,535 shares of FE common stock, par value $0.10 per
share, at a price of $39.08 per share, representing an investment of $1.0 billion. The transaction settled on December 13, 2021.
Issuance costs associated with the transaction were approximately $26 million as of December 31, 2021.
88
PREFERRED AND PREFERENCE STOCK
FirstEnergy and the Utilities were authorized to issue preferred stock and preference stock as of December 31, 2021, as follows:
Preferred Stock
Preference Stock
Shares
Authorized
Par Value
Shares
Authorized
Par Value
5,000,000 $
6,000,000 $
8,000,000 $
1,200,000 $
100
100
25
100
8,000,000
no par
no par
25
4,000,000
no par
3,000,000
5,000,000 $
3,000,000 $
12,000,000 $
15,600,000
10,000,000
11,435,000
940,000 $
10,000,000 $
32,000,000
100
25
no par
no par
no par
100
0.01
no par
FE
OE
OE
Penn
CEI
TE
TE
JCP&L
ME
PN
MP
PE
WP
As of December 31, 2021 and 2020, there were no preferred stock or preference stock outstanding.
Preferred Stock Issuance
In January of 2018, FE entered into a Preferred Stock Purchase Agreement for the private placement of 1,616,000 shares of
mandatorily convertible preferred stock, designated as the Series A Convertible Preferred Stock, par value $100 per share,
representing an investment of nearly $1.62 billion ($162 million of mandatorily convertible preferred stock and $1.46 billion of
OPIC).
During 2018, 911,411 shares of preferred stock were converted into 33,238,910 shares of common stock at the option of the
preferred stockholders. During 2019, the remaining 704,589 shares of preferred stock were converted into 25,696,168 shares of
common stock at the option of the preferred stockholders.
LONG-TERM DEBT AND OTHER LONG-TERM OBLIGATIONS
The following tables present outstanding long-term debt and finance lease obligations for FirstEnergy as of December 31, 2021
and 2020:
(Dollar amounts in millions)
As of December 31, 2021
As of December 31,
Maturity Date
Interest Rate
2021
2020
FMBs and secured notes - fixed rate
2022-2059
2.650% - 8.250% $
5,021 $
4,802
Unsecured notes - fixed rate
Finance lease obligations
Unamortized debt discounts
Unamortized debt issuance costs
Unamortized fair value adjustments
Currently payable long-term debt
2022-2050
1.600% - 7.375%
18,925
17,575
36
(8)
45
(34)
(126)
(118)
6
7
(1,606)
(146)
Total long-term debt and other long-term obligations
$ 22,248 $ 22,131
See Note 7, "Leases," for additional information related to finance leases.
89
During the twelve months ended December 31, 2021, the following long-term debt was issued:
Company
Issuance
Date
Interest
Rate
Maturity
Amount
Issuance Type
Use of Proceeds
FET
3/19/2021
2.87%
2028
$500 million
Unsecured
Notes
Repay short-term borrowings under the former FET Revolving
Facility.
MP
TE
4/9/2021
3.55% (1)
2027
$200 million
FMB
Fund MP’s ongoing capital expenditures, for working capital
needs and for other general corporate purposes.
5/6/2021
2.65%
2028
$150 million
Senior
Secured Notes
Repay short-term borrowings, fund TE’s ongoing capital
expenditures and for other general corporate purposes.
MAIT
5/24/2021
4.10% (2)
2028
$150 million
JCP&L
6/10/2021
2.75%
2032
$500 million
ATSI
12/1/2021
2.65%
2032
$600 million
Unsecured
Notes
Unsecured
Notes
Repay borrowings outstanding under FirstEnergy’s regulated
fund MAIT’s ongoing capital
company money pool,
expenditures, to fund working capital and for other general
corporate purposes.
Repay $450 million of short-term debt under the former FE
Revolving Facility, storm recovery and restoration costs and
expenses, to fund JCP&L’s ongoing capital expenditures,
working capital requirements and for other general corporate
purposes.
Unsecured
Notes
Repay outstanding notes and short-term borrowings, to fund
ATSI's ongoing capital expenditures, working capital
requirements and for other general corporate purposes.
(1) New debt was issued at a premium under a previously issued bond series, resulting in an effective interest rate of 2.06%.
(2) New debt was issued at a premium under a previously issued note series, resulting in an effective interest rate of 2.55%.
In December 2021, notice of redemption was provided for all remaining $850 million of FE's 4.25% Notes, Series B, due 2023,
which was completed on January 20, 2022, and with a make-whole premium of approximately $38 million. Due to the
redemption, the $850 million in notes is included within currently payable long-term debt on the Consolidated Balance Sheets as
of December 31, 2021.
On January 27, 2022, CEI instructed its indenture trustee to provide notice of redemption for all remaining $150 million of CEI's
2.77% Senior Notes, Series A, due 2034, for redemption to occur on March 14, 2022.
Also on January 27, 2022, TE instructed its indenture trustee to provide notice of partial redemption for $25 million of TE's 2.65%
Senior Secured Notes, due 2028, for partial redemption which occurred on February 11, 2022.
The following table presents scheduled debt repayments or debt that has been noticed for redemption for outstanding long-term
debt, excluding finance leases, fair value purchase accounting adjustments and unamortized debt discounts and premiums, for
the next five years as of December 31, 2021.
Year
2022
2023
2024
2025
2026
(In millions)
$
1,593
344
1,246
2,023
1,076
Securitized Bonds
Environmental Control Bonds
The consolidated financial statements of FirstEnergy include environmental control bonds issued by two bankruptcy remote,
special purpose limited liability companies that are indirect subsidiaries of MP and PE. Proceeds from the bonds were used to
construct environmental control facilities. Principal and interest owed on the environmental control bonds is secured by, and
payable solely from, the proceeds of the environmental control charges. Creditors of FirstEnergy, other than the limited liability
company SPEs, have no recourse to any assets or revenues of the special purpose limited liability companies. As of
December 31, 2021 and 2020, $274 million and $300 million of environmental control bonds were outstanding, respectively.
90
Phase-In Recovery Bonds
In June 2013, the SPEs formed by the Ohio Companies issued approximately $445 million of pass-through trust certificates
supported by phase-in recovery bonds to securitize the recovery of certain all electric customer heating discounts, fuel and
purchased power regulatory assets. The phase-in recovery bonds are payable only from, and secured by, phase in recovery
property owned by the SPEs. The bondholder has no recourse to the general credit of FirstEnergy or any of the Ohio
Companies. Each of the Ohio Companies, as servicer of its respective SPE, manages and administers the phase in recovery
property including the billing, collection and remittance of usage-based charges payable by retail electric customers. In the
aggregate, the Ohio Companies are entitled to annual servicing fees of $445 thousand that are recoverable through the usage-
based charges. The SPEs are considered VIEs and each one is consolidated into its applicable utility. As of December 31, 2021
and 2020, $222 million and $245 million of the phase-in recovery bonds were outstanding, respectively.
FMBs
The Ohio Companies and Penn each have a first mortgage indenture under which they can issue FMBs secured by a direct first
mortgage lien on substantially all of their property and franchises, other than specifically excepted property.
Debt Covenant Default Provisions
FirstEnergy has various debt covenants under certain financing arrangements, including its revolving credit facilities and term
loans. The most restrictive of the debt covenants relate to the nonpayment of interest and/or principal on such debt and the
maintenance of certain financial ratios. The failure by FirstEnergy to comply with the covenants contained in its financing
arrangements could result in an event of default, which may have an adverse effect on its financial condition. As of December 31,
2021, FirstEnergy remains in compliance with all debt covenant provisions.
Additionally, there are cross-default provisions in a number of the financing arrangements. These provisions generally trigger a
default in the applicable financing arrangement of an entity if it, or any of its significant subsidiaries, default under another
financing arrangement in excess of a certain principal amount, typically $100 million. Such defaults by any of the Utilities or
Transmission Companies would cross-default certain FE financing arrangements containing these provisions, and a certain FET
Financing arrangement, with respect to the Transmission Companies only, such defaults by AE Supply would not cross-default to
applicable financing arrangements of FE. Also, defaults by FE would generally not cross-default applicable financing
arrangements of any of FE’s subsidiaries. Cross-default provisions are not typically found in any of the senior notes or FMBs of
FE or its subsidiaries.
10. SHORT-TERM BORROWINGS AND BANK LINES OF CREDIT
FirstEnergy had no outstanding short-term borrowings as of December 31, 2021 and $2.2 billion of outstanding short-term
borrowings as of December 31, 2020.
On November 23, 2020, JCP&L, ME, Penn, TE and WP, borrowed $950 million in the aggregate under the former FE Revolving
Facility, bringing the outstanding principal balance to $1.2 billion, with $1.3 billion of remaining availability. On November 23,
2020, FET and ATSI borrowed $1 billion in the aggregate under the former FET Revolving Facility, bringing the outstanding
principal balance to $1 billion, with no remaining availability. FE, FET and certain of their respective subsidiaries increased their
borrowings under the former Revolving Facilities as a proactive measure to increase their respective cash positions and preserve
financial flexibility. These borrowings were repaid in full during 2021.
On October 18, 2021, FE, FET, the Utilities, and the Transmission Companies entered into the 2021 Credit Facilities, which were
six separate senior unsecured five-year syndicated revolving credit facilities with JPMorgan Chase Bank, N.A., Mizuho Bank, Ltd.
and PNC Bank, National Association that replaced the FE Revolving Facility and the FET Revolving Facility, and provide for
aggregate commitments of $4.5 billion. The 2021 Credit Facilities are available until October 18, 2026, as follows:
•
•
•
•
•
•
FE and FET, $1.0 billion revolving credit facility;
Ohio Companies, $800 million revolving credit facility;
Pennsylvania Companies, $950 million revolving credit facility;
JCP&L, $500 million revolving credit facility;
MP and PE, $400 million revolving credit facility; and
Transmission Companies, $850 million revolving credit facility.
Under the 2021 Credit Facilities, an aggregate amount of $4.5 billion is available to be borrowed, repaid and reborrowed, subject
to each borrower's respective sublimit under the respective facilities. These new credit facilities provide substantial liquidity to
support the Regulated Distribution and Regulated Transmission businesses, and each of the operating companies within the
businesses.
As of December 31, 2021, available liquidity under the 2021 Credit Facilities was $4.5 billion.
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Borrowings under the 2021 Credit Facilities may be used for working capital and other general corporate purposes. Generally,
borrowings under each of the credit facilities are available to each borrower separately and mature on the earlier of 364 days
from the date of borrowing or the commitment termination date, as the same may be extended. Each of the 2021 Credit Facilities
contain financial covenants requiring each borrower, with the exception of FE, to maintain a consolidated debt-to-total-
capitalization ratio (as defined under each of the 2021 Credit Facilities) of no more than 65%, and 75% for FET, measured at the
end of each fiscal quarter. FE is required under its 2021 Credit Facility to maintain a consolidated interest coverage ratio of not
less than 2.50 times, measured at the end of each fiscal quarter for the last four fiscal quarters beginning with the quarter ending
December 31, 2021.
Subject to each borrower's sublimit, the amounts noted below are available for the issuance of LOCs (subject to borrowings
drawn under the 2021 Credit Facilities) expiring up to one year from the date of issuance. The stated amount of outstanding
LOCs will count against total commitments available under each of the 2021 Credit Facilities and against the applicable
borrower's borrowing sublimit. As of December 31, 2021, FirstEnergy had $4 million in outstanding LOCs.
The 2021 Credit Facilities do not contain provisions that restrict the ability to borrow or accelerate payment of outstanding
advances in the event of any change in credit ratings of the borrowers. Pricing is defined in “pricing grids,” whereby the cost of
funds borrowed under the 2021 Credit Facilities are related to the credit ratings of the company borrowing the funds. Additionally,
borrowings under each of the 2021 Credit Facilities are subject to the usual and customary provisions for acceleration upon the
occurrence of events of default, including a cross-default for other indebtedness in excess of $100 million.
As of December 31, 2021, the borrowers were in compliance with the applicable interest coverage and debt-to-total-capitalization
ratio covenants in each case as defined under the respective 2021 Credit Facilities.
FirstEnergy Money Pools
FirstEnergy’s utility operating subsidiary companies also have the ability to borrow from each other and FE to meet their short-
term working capital requirements. Similar but separate arrangements exist among FirstEnergy’s unregulated companies with AE
Supply, FE, FET, FEV and certain other unregulated subsidiaries. FESC administers these money pools and tracks surplus funds
of FE and the respective regulated and unregulated subsidiaries, as the case may be, as well as proceeds available from bank
borrowings. Companies receiving a loan under the money pool agreements must repay the principal amount of the loan, together
with accrued interest, within 364 days of borrowing the funds. The rate of interest is the same for each company receiving a loan
from their respective pool and is based on the average cost of funds available through the pool. The average interest rate for
borrowings in 2021 was 1.01% per annum for the regulated companies’ money pool and 0.60% per annum for the unregulated
companies’ money pool.
Weighted Average Interest Rates
The annual weighted average interest rates on short-term borrowings outstanding as of December 31, 2021 and 2020, were
2.42% and 1.86%, respectively.
11. ASSET RETIREMENT OBLIGATIONS
FirstEnergy has recognized applicable legal obligations for AROs and their associated cost, including reclamation of sludge
disposal ponds, closure of coal ash disposal sites, underground and above-ground storage tanks and wastewater treatment
lagoons. In addition, FirstEnergy has recognized conditional retirement obligations, primarily for asbestos remediation.
The following table summarizes the changes to the ARO balances during 2021 and 2020:
ARO Reconciliation
Balance, January 1, 2020
Liabilities settled (1)
Accretion
Balance, December 31, 2020
Changes in timing and amount of estimated cash flows
Liabilities settled
Accretion
Balance, December 31, 2021
(In millions)
$
$
$
856
(744)
47
159
8
(1)
13
179
(1) Includes $726 million related to the closing of the asset purchase and sale agreement with TMI-2 Solutions, LLC, a subsidiary of
EnergySolutions, LLC, concerning the transfer and dismantlement of TMI-2.
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12. REGULATORY MATTERS
STATE REGULATION
Each of the Utilities' retail rates, conditions of service, issuance of securities and other matters are subject to regulation in the
states in which it operates - in Maryland by the MDPSC, in New Jersey by the NJBPU, in Ohio by the PUCO, in Pennsylvania by
the PPUC, in West Virginia by the WVPSC and in New York by the NYPSC. The transmission operations of PE in Virginia, ATSI
in Ohio, and the Transmission Companies in Pennsylvania are subject to certain regulations of the VSCC, PUCO and PPUC,
respectively. In addition, under Ohio law, municipalities may regulate rates of a public utility, subject to appeal to the PUCO if not
acceptable to the utility. Further, if any of the FirstEnergy affiliates were to engage in the construction of significant new
transmission facilities, depending on the state, they may be required to obtain state regulatory authorization to site, construct and
operate the new transmission facility.
The following table summarizes the key terms of base distribution rate orders in effect for the Utilities as of December 31, 2021:
Company
CEI
ME(1)
MP
JCP&L
OE
PE (West Virginia)
PE (Maryland)
PN(1)
Penn(1)
TE
WP(1)
Rates Effective
For Customers
May 2009
January 2017
February 2015
November 2021(3)
January 2009
February 2015
March 2019
January 2017
January 2017
January 2009
January 2017
Allowed Debt/
Equity
51% /49%
48.8% / 51.2%
54% / 46%
48.6% / 51.4%
51% /49%
54% / 46%
47% / 53%
47.4% /52.6%
49.9% / 50.1%
51% / 49%
49.7% / 50.3%
Allowed ROE
10.5%
Settled(2)
Settled(2)
9.6%
10.5%
Settled(2)
9.65%
Settled(2)
Settled(2)
10.5%
Settled(2)
(1) Reflects filed debt/equity as final settlement/orders do not specifically include capital structure.
(2) Commission-approved settlement agreements did not disclose ROE rates.
(3) On October 28, 2020, the NJBPU approved JCP&L's distribution rate case settlement with an allowed ROE of 9.6%
and a 48.6% debt / 51.4% equity capital structure. Rates are effective for customers on November 1, 2021, but
beginning January 1, 2021, JCP&L offset the impact to customers' bills by amortizing an $86 million regulatory liability.
MARYLAND
PE operates under MDPSC approved base rates that were effective as of March 23, 2019. PE also provides SOS pursuant to a
combination of settlement agreements, MDPSC orders and regulations, and statutory provisions. SOS supply is competitively
procured in the form of rolling contracts of varying lengths through periodic auctions that are overseen by the MDPSC and a
third-party monitor. Although settlements with respect to SOS supply for PE customers have expired, service continues in the
same manner until changed by order of the MDPSC. PE recovers its costs plus a return for providing SOS.
The EmPOWER Maryland program requires each electric utility to file a plan to reduce electric consumption and demand 0.2%
per year, up to the ultimate goal of 2% annual savings, for the duration of the 2021-2023 EmPOWER Maryland program cycles to
the extent the MDPSC determines that cost-effective programs and services are available. PE's approved 2021-2023
EmPOWER Maryland plan continues and expands upon prior years' programs for a projected total investment of approximately
$148 million over the three-year period. PE recovers program investments with a return through an annually reconciled
surcharge, with most costs subject to recovery over a five-year period with a return on the unamortized balance. Maryland law
only allows for the utility to recover lost distribution revenue attributable to energy efficiency or demand reduction programs
through a base rate case proceeding, and to date, such recovery has not been sought or obtained by PE.
In 2019, MDPSC issued an order approving PE’s 2018 base rate case filing, which among other things, approved an annual rate
increase of $6.2 million, approved three of the four EDIS programs for four years to fund enhanced service reliability programs,
directed PE to file a new depreciation study within 18 months, and ordered the filing of a new base rate case in four years to
correspond to the ending of the approved EDIS programs. Following the filing of PE’s depreciation study and subsequent filings
by the Maryland Office of the People’s Counsel and the staff of the MDPSC, the public utility law judge issued a proposed order
reducing PE’s base rates by $2.1 million. The MDPSC denied PE’s appeal of the proposed order on October 26, 2021, and the
proposed order was affirmed.
On April 9, 2020, the MDPSC issued an order allowing utilities to track and create a regulatory asset for future recovery of all
prudently incurred incremental costs arising from the COVID-19 pandemic, including incremental uncollectible expense, incurred
from the date of the Governor’s order (or earlier if the utility could show that the expenses related to suspension of service
terminations). On June 16, 2021, the MDPSC provided PE with approximately $4 million of COVID-19 relief funds that was
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allocated by the Maryland General Assembly to be used to reduce certain residential customer utility account receivable
arrearages.
NEW JERSEY
JCP&L operates under NJBPU approved rates that were effective for customers as of November 1, 2021. JCP&L provides BGS
for retail customers who do not choose a third-party EGS and for customers of third-party EGSs that fail to provide the contracted
service. All New Jersey EDCs participate in this competitive BGS procurement process and recover BGS costs directly from
customers as a charge separate from base rates.
In December 2017, the NJBPU issued proposed rules to modify its current CTA policy in base rate cases to: (i) calculate savings
using a five-year look back from the beginning of the test year; (ii) allocate savings with 75% retained by the company and 25%
allocated to customers; and (iii) exclude transmission assets of electric distribution companies in the savings calculation. On
January 17, 2019, the NJBPU approved the proposed CTA rules with no changes. On May 17, 2019, the NJ Rate Counsel filed
an appeal with the Appellate Division of the Superior Court of New Jersey and on June 7, 2021, the Superior Court issued an
order reversing the NJBPU’s CTA rules and remanded the case back to the NJBPU. Specifically, the Court’s ruling requires
100% of the CTA savings to be credited to customers in lieu of the NJBPU’s current policy requiring 25%. On December 6, 2021,
the NJBPU issued proposed amended rules modifying its current CTA policy in base rate cases consistent with the Superior
Court’s June 7, 2021 order. Once the proposed rules are final, they will be applied on a prospective basis in a future base rate
case, however, it is not expected to have a material adverse effect on FirstEnergy’s results or financial condition.
On February 18, 2020, JCP&L submitted a filing with the NJBPU requesting a distribution base rate increase. On October 28,
2020, the NJBPU approved a stipulated settlement between JCP&L and various parties, providing for, among other things, a $94
million annual base distribution revenues increase for JCP&L based on an ROE of 9.6%, which became effective for customers
on November 1, 2021. Between January 1, 2021 and October 31, 2021, JCP&L amortized an existing regulatory liability totaling
approximately $86 million to offset the base rate increase that otherwise would have occurred in this period. The parties also
agreed that the actual net gain from the sale of JCP&L’s interest in the Yards Creek pumped-storage hydro generation facility in
New Jersey (210 MWs), as further discussed below, be applied to reduce JCP&L’s existing regulatory asset for previously
deferred storm costs. Lastly, the parties agreed that approximately $95 million of Reliability Plus capital investment for projects
through December 31, 2020, is included in rate base effective December 31, 2020. Included in the NJBPU approved-settlement
in JCP&L’s distribution rate case on October 28, 2020, was that JCP&L will be subject to a management audit. The management
audit began at the end of May 2021 and is currently ongoing.
On April 6, 2020, JCP&L signed an asset purchase agreement with Yards Creek Energy, LLC, a subsidiary of LS Power to sell its
50% interest in the Yards Creek pumped-storage hydro generation facility. Subject to terms and conditions of the agreement, the
base purchase price is $155 million. As of December 31, 2020, assets held for sale on FirstEnergy’s Consolidated Balance
Sheets associated with the transaction consist of property, plant and equipment of $45 million, which is included in the regulated
distribution segment. On July 31, 2020, FERC approved the transfer of JCP&L’s interest in the hydroelectric operating license.
On October 8, 2020, FERC issued an order authorizing the transfer of JCP&L’s ownership interest in the hydroelectric facilities.
On October 28, 2020, the NJBPU approved the sale of Yards Creek. With the receipt of all required regulatory approvals, the
transaction was consummated on March 5, 2021 and resulted in a $109 million gain within the regulated distribution segment. As
further discussed above, the gain from the transaction was applied against and reduced JCP&L’s existing regulatory asset for
previously deferred storm costs and, as a result, was offset by expense in the “Amortization of regulatory assets, net”, line on the
Consolidated Statements of Income, resulting in no earnings impact to FirstEnergy or JCP&L.
On August 27, 2020, JCP&L filed an AMI Program with the NJBPU, which proposed the deployment of approximately 1.2 million
advanced meters over a three-year period beginning on January 1, 2023, at a total cost of approximately $418 million, including
the pre-deployment phase. The then proposed 3-year deployment was part of the 20-year AMI Program that was projected to
cost approximately $732 million and proposed a cost recovery mechanism through a separate AMI tariff rider. On September 14,
2021, JCP&L submitted a supplemental filing, which reflected increases in the AMI Program’s costs. Under the revised AMI
Program, during the first six years of the AMI Program from 2022 through 2027, JCP&L estimates costs of $494 million,
consisting of capital expenditures of approximately $390 million, incremental operations and maintenance expenses of
approximately $73 million and cost of removal of $31 million. On February 8, 2022, JCP&L filed with the NJBPU a stipulation
entered into with the NJBPU staff, NJ Rate Counsel and others, that, pending NJBPU approval, would affirm the terms of the
revised AMI Program. JCP&L expects a NJBPU order by the end of the first quarter of 2022. The Stipulation also provided that
the revised AMI Program-related capital costs, the legacy meter stranded costs, and the operations and maintenance expense
will be deferred and placed in regulatory assets, with such amounts sought to be recovered in the JCP&L’s subsequent base rate
cases.
On June 10, 2020, the NJBPU issued an order establishing a framework for the filing of utility-run energy efficiency and peak
demand reduction programs in accordance with the New Jersey Clean Energy Act. Under the established framework, JCP&L will
recover its program investments with a return over a ten-year amortization period and its operations and maintenance expenses
on an annual basis, be eligible to receive lost revenues on energy savings that resulted from its programs and be eligible for
incentives or subject to penalties based on its annual program performance, beginning in the fifth year of its program offerings.
On September 25, 2020, JCP&L filed its energy efficiency and peak demand reduction program, which consists of 11 energy
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efficiency and peak demand reduction programs and subprograms to be run from July 1, 2021, through June 30, 2024. On April
23, 2021, JCP&L filed a Stipulation of Settlement with the NJBPU for approval of recovery of lost revenues resulting from the
programs and a three-year plan including total program costs of $203 million, of which $158 million of investment is recovered
over a ten-year amortization period with a return as well as operations and maintenance expenses and financing costs of $45
million recovered on an annual basis. On April 27, 2021, the NJBPU issued an Order approving the Stipulation of Settlement.
On July 2, 2020, the NJBPU issued an order allowing New Jersey utilities to track and create a regulatory asset for future
recovery of all prudently incurred incremental costs arising from the COVID-19 pandemic beginning March 9, 2020 and
continuing until the New Jersey Governor issues an order stating that the COVID-19 pandemic is no longer in effect. New Jersey
utilities can request recovery of such regulatory asset in a stand-alone COVID-19 regulatory asset filing or future base rate case.
On October 28, 2020, the NJBPU issued an order expanding the scope of the proceeding to examine all pandemic issues,
including recovery of the COVID-19 regulatory assets, by way of a generic proceeding. Through various executive orders issued
by the New Jersey Governor, the moratorium period was extended to December 31, 2021. On December 21, 2021, the
moratorium on residential disconnections for certain entities providing utility service was extended until March 15, 2022. The
moratorium on residential disconnections was not extended for investor-owned electric utilities such as JCP&L, but does require
that investor-owned electric public utilities offer qualifying residential customers deferred payment arrangements meeting certain
minimum criteria prior to disconnecting service.
Credit rating actions taken by S&P and Fitch on October 28, 2020 triggered a requirement from various NJBPU orders that
JCP&L file a mitigation plan, which was filed on November 5, 2020, to demonstrate that JCP&L has sufficient liquidity to meet its
BGS obligations. On December 11, 2020, the NJBPU held a public hearing on the mitigation plan. Written comments on JCP&L’s
mitigation plan were submitted on January 8, 2021.
Pursuant to an NJBPU order requiring all New Jersey electric distribution companies to file electric vehicle programs, JCP&L filed
its program on March 1, 2021. JCP&L’s proposed electric vehicle program consisted of six sub-programs, including a consumer
education and outreach initiative that would begin on January 1, 2022, and continue over a four-year period. The total proposed
budget for the electric vehicle program is approximately $50 million, of which $16 million is capital expenditures and $34 million is
for operations and maintenance expenses. JCP&L is proposing to recover the electric vehicle program costs via a non-
bypassable rate clause applicable to all distribution customer rate classes, which became effective on January 1, 2022. On May
26, 2021, a procedural schedule was set to include evidentiary hearings the week of October 18, 2021. On July 16, 2021, the
procedural schedule was extended by thirty days as requested by JCP&L to continue settlement discussions. On August 19,
2021, the presiding commissioner issued an order modifying the procedural schedule by extending the procedural schedule by
ninety days as requested by JCP&L to continue settlement discussions. On November 12, 2021, JCP&L filed a letter with the
presiding commissioner requesting a suspension of the procedural schedule in order to allow the parties to continue settlement
discussion. On November 23, 2021, the presiding commissioner entered an order suspending the procedural schedule. JCP&L
expects an order from the NJBPU by the end of the first quarter of 2022.
OHIO
The Ohio Companies operate under PUCO approved base distribution rates that became effective in 2009. The Ohio Companies
currently operate under ESP IV, effective June 1, 2016 and continuing through May 31, 2024, that continues the supply of power
to non-shopping customers at a market-based price set through an auction process. ESP IV also continues the Rider DCR,
which supports continued investment related to the distribution system for the benefit of customers, with increased revenue caps
of $20 million per year from June 1, 2019 through May 31, 2022; and $15 million per year from June 1, 2022 through May 31,
2024. In addition, ESP IV includes: (1) continuation of a base distribution rate freeze through May 31, 2024; (2) a goal across
FirstEnergy to reduce CO2 emissions by 90% below 2005 levels by 2045; and (3) contributions, totaling $51 million to: (a) fund
energy conservation programs, economic development and job retention in the Ohio Companies’ service territories; (b) establish
a fuel-fund in each of the Ohio Companies’ service territories to assist low-income customers; and (c) establish a Customer
Advisory Council to ensure preservation and growth of the competitive market in Ohio.
ESP IV further provided for the Ohio Companies to collect DMR revenues, but the SCOH reversed the PUCO’s decision to
include DMR in ESP IV. Subsequently, the PUCO entered an order directing the Ohio Companies to cease further collection
through the DMR and credit back to customers a refund of the DMR funds collected since July 2, 2019. On December 1, 2020,
the SCOH reversed the PUCO’s exclusion of the DMR revenues from the determination of the existence of significantly
excessive earnings under ESP IV for OE for calendar year 2017, and remanded the case to the PUCO with instructions to
conduct new proceedings which include the DMR revenues in the analysis, determine the threshold against which the earned
return is measured, and make other necessary determinations. As further described below, the Ohio Stipulation resolves the
Ohio Companies’ 2017 SEET proceeding.
On July 23, 2019, Ohio enacted HB 6, which included provisions supporting nuclear energy, authorizing a decoupling mechanism
for Ohio electric utilities and ending current energy efficiency program mandates. Under HB 6, the energy efficiency program
mandates, as well as Ohio electric utilities’ energy efficiency and peak demand reduction cost recovery riders, ended on
December 31, 2020, subject to final reconciliation. Third-parties have challenged the Ohio Companies’ authorization to recover
all lost distribution revenue under energy efficiency and peak demand reduction cost recovery riders. The Ohio Stipulation
resolves the issues related to lost distribution revenue with no financial impact to the Ohio Companies.
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On March 31, 2021, the Ohio Governor signed HB 128, which, among other things, repealed parts of HB 6, the legislation that
established support for nuclear energy supply in Ohio, provided for a decoupling mechanism for Ohio electric utilities, and
provided for the ending of current energy efficiency program mandates. HB 128 was effective June 30, 2021. As FirstEnergy
would not have financially benefited from the mechanism to provide support to nuclear energy in Ohio, there is no expected
additional impact to FirstEnergy due to the repeal of that provision in HB 6.
As further discussed below, in connection with a partial settlement with the OAG and other parties, the Ohio Companies filed an
application with the PUCO on February 1, 2021, to set the respective decoupling riders (CSR) to zero. On February 2, 2021, the
PUCO approved the application. While the partial settlement with the OAG focused specifically on decoupling, the Ohio
Companies elected to forego recovery of lost distribution revenue. FirstEnergy also committed to pursuing an open dialogue with
stakeholders in an appropriate manner with respect to the numerous regulatory proceedings then underway as further discussed
herein. As a result of the partial settlement, and the decision to not seek lost distribution revenue, FirstEnergy recognized a $108
million pre-tax charge ($84 million after-tax) in the fourth quarter of 2020, and $77 million (pre-tax) of which is associated with
forgoing collection of lost distribution revenue. The Ohio Stipulation affirms the Ohio Companies’ commitment to not seek
recovery of lost distribution revenue through the end of its ESP IV in May 2024.
On March 31, 2021, FirstEnergy announced that the Ohio Companies would refund to customers amounts previously collected
under decoupling, with interest, totaling approximately $27 million. On July 7, 2021, the PUCO issued an order approving the
Ohio Companies’ modified application to refund such amounts to customers and directed that all funds collected through CSR be
refunded to customers over a single billing cycle beginning August 1, 2021.
In connection with the audit of the Ohio Companies’ Rider DCR for 2017, the PUCO issued an order on June 16, 2021, directing
the Ohio Companies to prospectively discontinue capitalizing certain vegetation management costs and reduce the 2017 Rider
DCR revenue requirement by $3.7 million associated with these costs.
On September 8, 2020, the OCC filed motions in the Ohio Companies’ corporate separation audit and DMR audit dockets,
requesting the PUCO to open an investigation and management audit, hire an independent auditor, and require FirstEnergy to
show it did not improperly use money collected from consumers or violate any utility regulatory laws, rules or orders in its
activities regarding HB 6. On December 30, 2020, in response to the OCC's motion, the PUCO reopened the DMR audit docket,
and directed PUCO staff to solicit a third-party auditor and conduct a full review of the DMR to ensure funds collected from
customers through the DMR were only used for the purposes established in ESP IV. On June 2, 2021, the PUCO selected an
auditor. The auditor filed the final audit report on January 14, 2022, which made findings and recommendations. The report found
that spending of DMR revenues was not required to be tracked, and that DMR revenues, like all rider revenues, are placed into
the regulated money pool as a matter of routine, where the funds lose their identify. Therefore, the report could not suggest that
DMR funds were used definitively for direct or indirect support for grid modernization. The report also concluded that there was
no documented evidence that ties revenues from the DMR to lobbying for the passage of HB 6, but also could not rule out with
certainty uses of DMR funds to support the passage of HB 6. The report further recommended that the regulated companies'
money pool be audited more frequently and the Ohio Companies adopt formal dividend policies.
On September 15, 2020, the PUCO opened a new proceeding to review the political and charitable spending by the Ohio
Companies in support of HB 6 and the subsequent referendum effort, and directing the Ohio Companies to show cause,
demonstrating that the costs of any political or charitable spending in support of HB 6, or the subsequent referendum effort, were
not included, directly or indirectly, in any rates or charges paid by customers. The Ohio Companies initially filed a response
stating that the costs of any political or charitable spending in support of HB 6, or the subsequent referendum effort, were not
included, directly or indirectly, in any rates or charges paid by customers, but on August 6, 2021, filed a supplemental response
explaining that, in light of the facts set forth in the DPA and the findings of the Rider DCR audit report further discussed below,
political or charitable spending in support of HB 6, or the subsequent referendum effort, affected pole attachment rates paid by
approximately $15 thousand. On October 26, 2021, the OCC filed a motion requesting the PUCO to order an independent
external audit to investigate FE’s political and charitable spending related to HB 6, and to appoint an independent review panel to
retain and oversee the auditor. In November and December 2021, parties filed comments and reply comments regarding the
Ohio Companies’ original and supplemental responses to the PUCO’s September 15, 2020, show cause directive.
In connection with an ongoing audit of the Ohio Companies’ policies and procedures relating to the code of conduct rules
between affiliates, on November 4, 2020, the PUCO initiated an additional corporate separation audit as a result of the
FirstEnergy leadership transition announcement made on October 29, 2020, as further discussed below. The additional audit is
to ensure compliance by the Ohio Companies and their affiliates with corporate separation laws and the Ohio Companies’
corporate separation plan. The additional audit is for the period from November 2016 through October 2020. The final audit
report was filed on September 13, 2021. The audit report makes no findings of major non-compliance with Ohio corporate
separation requirements, minor non-compliance with eight requirements, and findings of compliance with 23 requirements.
Parties filed comments and reply comments on the audit report, and a PUCO attorney examiner has issued a procedural
schedule setting an evidentiary hearing on May 9, 2022.
In the fourth quarter of 2020, motions were filed with the PUCO requesting that the PUCO amend the Ohio Companies’ riders for
collecting the OVEC related charges required by HB 6, which the Ohio Companies are further required to remit to other Ohio
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electric distribution utilities or to the State Treasurer, to provide for refunds in the event such provisions of HB 6 are repealed.
The Ohio Companies contested the motions, which are pending before the PUCO.
On December 7, 2020, the Citizens’ Utility Board of Ohio filed a complaint with the PUCO against the Ohio Companies. The
complaint alleges that the Ohio Companies’ new charges resulting from HB 6, and any increased rates resulting from
proceedings over which the former PUCO Chairman presided, are unjust and unreasonable, and that the Ohio Companies
violated Ohio corporate separation laws by failing to operate separately from unregulated affiliates. The complaint requests,
among other things, that any rates authorized by HB 6 or authorized by the PUCO in a proceeding over which the former
Chairman presided be made refundable; that the Ohio Companies be required to file a new distribution rate case at the earliest
possible date; and that the Ohio Companies’ corporate separation plans be modified to introduce institutional controls. The Ohio
Companies are contesting the complaint. On December 21, 2021, the Citizens’ Utility Board of Ohio filed a notice of voluntary
dismissal of its complaint without prejudice. The PUCO dismissed the complaint without prejudice on January 12, 2022.
On November 1, 2021, the Ohio Companies, together with the OCC, PUCO Staff, and several other signatories, entered into an
Ohio Stipulation with the intent of resolving the ongoing energy efficiency rider audits, various SEET, proceedings, including the
Ohio Companies’ 2017 SEET proceeding, and the Ohio Companies’ quadrennial ESP review, each of which was pending before
the PUCO. Specifically, the Ohio Stipulation provides that the Ohio Companies’ current ESP IV passes the required statutory test
for their prospective SEET review as part of the Quadrennial Review of ESP IV, and except for limited circumstances, the
signatory parties have agreed not to challenge the Ohio Companies’ SEET return on equity calculation methodology for their
2021-2024 SEET proceedings. The Ohio Stipulation additionally affirms that: (i) the Ohio Companies’ ESP IV shall continue
through its previously authorized term of May 31, 2024; and (ii) the Ohio Companies will file their next base rate case in May
2024, and further, no signatory party will seek to adjust the Ohio Companies’ base distribution rates before that time, except in
limited circumstances. The Ohio Companies further agreed to refund $96 million to customers in connection with the 2017-2019
SEET cases, and to provide $210 million in future rate reductions for all customers, including $80 million in 2022, $60 million in
2023, $45 million in 2024, and $25 million in 2025. The PUCO approved the 2017-2019 SEET refunds and 2022 rate reductions
December 1, 2021, and refunds began in January 2022. As a result of the PUCO approval, FirstEnergy recognized a $96 million
pre-tax charge in the fourth quarter of 2021 at the regulated distribution segment within Amortization (deferral) of Regulatory
Assets, net, on the Consolidated Statements of Income associated with the refund. The future rate reductions will be recognized
as a reduction to regulated distribution segment’s revenue in the Consolidated Statements of Income as they are provided to the
Ohio Companies’ customers.
In connection with an ongoing annual audit of the Ohio Companies’ Rider DCR for 2020, and as a result of disclosures in
FirstEnergy’s Form 10-K for the year ended December 31, 2020 (filed on February 18, 2021), the PUCO expanded the scope of
the audit on March 10, 2021, to include a review of certain transactions that were either improperly classified, misallocated, or
lacked supporting documentation, and to determine whether funds collected from customers were used to pay the vendors, and
if so, whether or not the funds associated with those payments should be returned to customers through Rider DCR or through
an alternative proceeding. On August 3, 2021, the auditor filed its final report on this phase of the audit, and the parties submitted
comments and reply comments on this audit report in October 2021. Additionally, on September 29, 2021, the PUCO expanded
the scope of the audit in this proceeding to determine if the costs of the naming rights for FirstEnergy Stadium have been
recovered from the Ohio Companies’ customers. On November 19, 2021, the auditor filed its final report, in which the auditor
concluded that the FirstEnergy Stadium naming rights expenses were not recovered from Ohio customers. On December 15,
2021, the PUCO further expanded the scope of the audit to include an investigation into an apparent nondisclosure of a side
agreement in the Ohio Companies’ ESP IV settlement proceedings, but stayed its expansion of the audit until otherwise ordered
by the PUCO.
See Note 13, "Commitments, Guarantees and Contingencies" below for additional details on the government investigations and
subsequent litigation surrounding the investigation of HB 6.
PENNSYLVANIA
The Pennsylvania Companies operate under rates approved by the PPUC, effective as of January 27, 2017. On November 18,
2021, the PPUC issued orders to each of the Pennsylvania Companies directing they operate under DSPs for the June 1, 2019
through May 31, 2023 delivery period, which DSPs provide for the competitive procurement of generation supply for customers
who do not receive service from an alternative EGS. Under the 2019-2023 DSPs, supply will be provided by wholesale suppliers
through a mix of 3, 12 and 24-month energy contracts, as well as two RFPs for 2-year SREC contracts for ME, PN and Penn. On
December 14, 2021, the Pennsylvania Companies filed proposed DSPs for provision of generation for the June 1, 2023 through
May 31, 2027 delivery period, to be sourced through competitive procurements for customers who do not receive service from an
alternative EGS. Under the 2023-2027 DSPs, supply is proposed to be provided through a mix of 12 and 24-month energy
contracts, as well as long-term solar PPAs.
In March 2018, the PPUC approved adjusted customer rates of the Pennsylvania Companies to reflect the net impact of the Tax
Act. As a result, the Pennsylvania Companies established riders that, beginning July 1, 2018, refunded to customers tax savings
attributable to the Tax Act as compared to the amounts established in their most recent base rate proceedings on a current and
going forward basis. The amounts recorded as savings for the total period of January 1 through June 30, 2018, were tracked and
were to be addressed for treatment in a future proceeding. On May 17, 2021, the Pennsylvania Companies filed petitions with
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the PPUC proposing to refund the net savings for the January through June 2018 period to customers beginning January 1,
2022. On November 18, 2021, the PPUC approved the Pennsylvania Companies' proposed refunds, but also revised a previous
methodology for calculating the net tax savings, which resulted in additional tax savings attributable to the Tax Act to be refunded
to customers and directed the Pennsylvania Companies to file new petitions to propose the timing and methodology to provide
these additional refunds to customers. The Pennsylvania Companies recalculated the net impact for 2018 through 2021 under
the revised PPUC methodology in comparison to amounts already refunded to customers under the existing riders, which
resulted in an additional $61 million in savings, with interest, to be provided to customers. As a result, FirstEnergy recognized a
pre-tax charge of $61 million in the fourth quarter of 2021 at the regulated distribution segment within Amortization (deferral) of
Regulatory Assets, net, on the Consolidated Statement of Income associated with the additional refund associated with the
November 2021 PPUC order and methodology. The Pennsylvania Companies are required to file petitions to propose the timing
and methodology of the refund of these amounts by March 3, 2022.
Pursuant to Pennsylvania Act 129 of 2008 and PPUC orders, Pennsylvania EDCs implement energy efficiency and peak demand
reduction programs. The Pennsylvania Companies’ Phase III EE&C plans for the June 2016 through May 2021 period, which
were approved in March 2016, with expected costs up to $390 million, are designed to achieve the targets established in the
PPUC’s Phase III Final Implementation Order with full recovery through the reconcilable EE&C riders. On June 18, 2020, the
PPUC entered a Final Implementation Order for a Phase IV EE&C Plan, operating from June 2021 through May 2026. The Final
Implementation Order set demand reduction targets, relative to 2007 to 2008 peak demands, at 2.9% MW for ME, 3.3% MW for
PN, 2.0% MW for Penn, and 2.5% MW for WP; and energy consumption reduction targets, as a percentage of the Pennsylvania
Companies’ historic 2009 to 2010 reference load at 3.1% MWH for ME, 3.0% MWH for PN, 2.7% MWH for Penn, and 2.4%
MWH for WP. The Pennsylvania Companies’ Phase IV plans were filed November 30, 2020 and subsequently approved by
PPUC without modification on March 25, 2021.
Pennsylvania EDCs are permitted to seek PPUC approval of an LTIIP for infrastructure improvements and costs related to
highway relocation projects, after which a DSIC may be approved to recover LTIIP costs. On January 16, 2020, the PPUC
approved the Pennsylvania Companies’ LTIIPs for the five-year period beginning January 1, 2020 and ending December 31,
2024 for a total capital investment of approximately $572 million for certain infrastructure improvement initiatives. On June 25,
2021, the Pennsylvania OCA filed a complaint against Penn’s quarterly DSIC rate, disputing the recoverability of the Companies’
automated distribution management system investment under the DSIC mechanism. On January 26, 2022, the parties filed a
joint petition for settlement that resolves all issues in this matter pending PPUC approval.
Following the Pennsylvania Companies’ 2016 base rate proceedings, the PPUC ruled in a separate proceeding related to the
DSIC mechanisms that the Pennsylvania Companies were not required to reflect federal and state income tax deductions related
to DSIC-eligible property in DSIC rates. The decision was appealed to the Pennsylvania Supreme Court and in July 2021 the
court upheld the Pennsylvania Commonwealth Court’s reversal of the PPUC’s decision and remanded the matter back to the
PPUC for determination as to how DSIC calculations shall account for ADIT and state taxes. The matter awaits further action by
the PPUC. The adverse ruling by the Pennsylvania Supreme Court is not expected to result in a material impact to FirstEnergy.
The PPUC issued an order on March 13, 2020, forbidding utilities from terminating service for non-payment for the duration of
the COVID-19 pandemic. On May 13, 2020, the PPUC issued a Secretarial letter directing utilities to track all prudently incurred
incremental costs arising from the COVID-19 pandemic, and to create a regulatory asset for future recovery of incremental
uncollectibles incurred as a result of the COVID-19 pandemic and termination moratorium. On October 13, 2020, the PPUC
entered an order lifting the service termination moratorium effective November 9, 2020, subject to certain additional notification,
payment procedures and exceptions, and permits the Pennsylvania Companies to create a regulatory asset for all incremental
expenses associated with their compliance with the order. On March 19, 2021, the PPUC entered an order lifting the moratorium
in total effective March 31, 2021, subject to certain additional guidelines regarding the duration of payment arrangements and
reporting obligations.
WEST VIRGINIA
MP and PE provide electric service to all customers through traditional cost-based, regulated utility ratemaking and operate
under WVPSC approved rates that became effective in February 2015. MP and PE recover net power supply costs, including
fuel costs, purchased power costs and related expenses, net of related market sales revenue through the ENEC. MP’s and PE’s
ENEC rate is updated annually.
On December 30, 2020, MP and PE filed with the WVPSC a determination of the rate impact of the Tax Act with respect to ADIT.
The filing proposed an annual revenue reduction of $2.6 million, effective January 1, 2022, with reconciliation and any resulting
adjustments incorporated into annual ENEC proceedings. On August 12, 2021, a unanimous settlement was reached with all the
parties agreeing to a $7.7 million rate reduction beginning January 1, 2022, with a true-up in the ENEC proceeding each year. On
November 30, 2021, the WVPSC approved the settlement on all terms, except for the proposed effective date of the rate
reduction, which was held in abeyance until further notice.
On August 27, 2021, MP and PE filed with the WVPSC their annual ENEC case requesting an increase in ENEC rates of $19.6
million beginning January 1, 2022, which represented a 1.5% increase to the rates currently in effect. WVPSC issued an order on
December 29, 2021, granting the requested $19.6 million increase in ENEC rates. Among other things, the order requires MP
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and PE to refund to its large industrial customers their respective portion of the $7.7 million rate reduction discussed above and
also requires MP and PE to negotiate a PPA for its capacity shortfall and a reasonable reserve margin if certain conditions are
met.
On November 22, 2021, MP and PE filed with the WVPSC their plan to construct 50 MWs of solar generation at five sites in West
Virginia. The plan includes a tariff to offer solar power to West Virginia customers and cost recovery for MP and PE from other
customers through a surcharge for any solar investment not fully subscribed by their customers. A hearing has been set for
March 16, 2022. The solar generation project is expected to cost approximately $100 million and begin being in-service by the
end of 2023 and finalized no later than the end of 2025.
On August 27, 2021, MP and PE filed with the WVPSC a biennial review of the vegetation management surcharge seeking a $16
million annual revenue increase. A settlement among the parties was reached on December 3, 2021 and on December 27, 2021,
the WVPSC approved the settlement, which granted a $16 million increase in rates, and continued the vegetation management
program and surcharge for another two years. Additionally, the WVPSC order added a provision requiring equipment inspections
be performed within a reasonable time after vegetation management occurs on a circuit.
On December 17, 2021, MP and PE filed with the WVPSC for approval of environmental compliance projects at the Ft. Martin
and Harrison Power Stations to comply with the EPA’s ELG and operate these plants beyond 2028. The request includes a
surcharge to recover the expected $142 million capital investment and $3 million in annual operation and maintenance expense.
A ruling from the WVPSC is expected in mid-summer 2022, and if approved, construction would be expected to be completed by
the end of 2025. See "Environmental Matters - Clean Water Act" below, for additional details on the EPA's ELG.
FERC REGULATORY MATTERS
Under the FPA, FERC regulates rates for interstate wholesale sales, transmission of electric power, accounting and other
matters, including construction and operation of hydroelectric projects. With respect to their wholesale services and rates, the
Utilities, AE Supply and the Transmission Companies are subject to regulation by FERC. FERC regulations require JCP&L, MP,
PE, WP and the Transmission Companies to provide open access transmission service at FERC-approved rates, terms and
conditions. Transmission facilities of JCP&L, MP, PE, WP and the Transmission Companies are subject to functional control by
PJM and transmission service using their transmission facilities is provided by PJM under the PJM Tariff.
The following table summarizes the key terms of rate orders in effect for transmission customer billings for FirstEnergy's
transmission owner entities as of December 31, 2021:
Company
ATSI
JCP&L
MP
PE
WP
MAIT
TrAIL
Rates Effective
Capital Structure
Allowed ROE
January 1, 2015
Actual (13-month average)
January 1, 2020
January 1, 2021(1)(2)
January 1, 2021(1)(2)
January 1, 2021(1)(2)
July 1, 2017
Actual (13-month average)
Actual (13-month average)(1)
Actual (13-month average)(1)
Actual (13-month average)(1)
Lower of Actual (13-month
average) or 60%
10.38%
10.20%
11.35%(1)
11.35%(1)
11.35%(1)
10.3%
July 1, 2008
Actual (year-end)
12.7%(TrAIL the Line & Black Oak SVC)
11.7% (All other projects)
(1) Effective on January 1, 2021, MP, PE, and WP have implemented a forward-looking formula rate, which has been accepted
by FERC, subject to refund, pending further hearing and settlement procedures.
(2) See FERC Action on Tax Act below.
FERC regulates the sale of power for resale in interstate commerce in part by granting authority to public utilities to sell
wholesale power at market-based rates upon showing that the seller cannot exert market power in generation or transmission or
erect barriers to entry into markets. The Utilities and AE Supply each have been authorized by FERC to sell wholesale power in
interstate commerce at market-based rates and have a market-based rate tariff on file with FERC, although in the case of the
Utilities major wholesale purchases remain subject to review and regulation by the relevant state commissions.
Federally enforceable mandatory reliability standards apply to the bulk electric system and impose certain operating, record-
keeping and reporting requirements on the Utilities, AE Supply, and the Transmission Companies. NERC is the ERO designated
by FERC to establish and enforce these reliability standards, although NERC has delegated day-to-day implementation and
enforcement of these reliability standards to six regional entities, including RFC. All of the facilities that FirstEnergy operates are
located within RFC. FirstEnergy actively participates in the NERC and RFC stakeholder processes, and otherwise monitors and
manages its companies in response to the ongoing development, implementation and enforcement of the reliability standards
implemented and enforced by RFC.
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FirstEnergy believes that it is in material compliance with all currently effective and enforceable reliability standards.
Nevertheless, in the course of operating its extensive electric utility systems and facilities, FirstEnergy occasionally learns of
isolated facts or circumstances that could be interpreted as excursions from the reliability standards. If and when such
occurrences are found, FirstEnergy develops information about the occurrence and develops a remedial response to the specific
circumstances, including in appropriate cases “self-reporting” an occurrence to RFC. Moreover, it is clear that NERC, RFC and
FERC will continue to refine existing reliability standards as well as to develop and adopt new reliability standards. Any inability
on FirstEnergy’s part to comply with the reliability standards for its bulk electric system could result in the imposition of financial
penalties, or obligations to upgrade or build transmission facilities, that could have a material adverse effect on its financial
condition, results of operations and cash flows.
FERC Audit
FERC’s Division of Audits and Accounting initiated a nonpublic audit of FESC in February 2019. Among other matters, the audit
is evaluating FirstEnergy’s compliance with certain accounting and reporting requirements under various FERC regulations. On
February 4, 2022, FERC filed the final audit report for the period of January 1, 2015 through September 30, 2021, which included
several findings and recommendations. One of the audit report findings and related recommendations state that FirstEnergy may
have used an inappropriate methodology for allocation of certain costs to regulatory capital accounts under certain FERC
regulations and reporting. Based on the finding and related recommendations, FirstEnergy is currently performing an analysis of
these costs and how it impacted certain wholesale transmission customer rates. FirstEnergy is unable to predict or estimate the
final outcome of this analysis and audit, however, it could result in refunds, with interest, to certain wholesale transmission
customers and/or write-offs of previously capitalized costs if they are determined to be nonrecoverable.
ATSI Transmission Formula Rate
On May 1, 2020, ATSI filed amendments to its formula rate to recover regulatory assets for certain costs that ATSI incurred as a
result of its 2011 move from MISO to PJM, certain costs allocated to ATSI by FERC for transmission projects that were
constructed by other MISO transmission owners, and certain costs for transmission-related vegetation management programs. A
portion of these costs would have been charged to the Ohio Companies. Additionally, ATSI proposed certain income tax-related
adjustments and certain tariff changes addressing the revenue credit components of the formula rate template. On June 30,
2020, FERC issued an initial order accepting the tariff amendments subject to refund and setting the matter for hearing and
settlement proceedings. ATSI and the parties to the FERC proceeding subsequently were able to reach settlement, and on
October 14, 2021, filed the settlement with FERC. As a result of the filed settlement, FirstEnergy recognized a $21 million pre-tax
charge during the third quarter of 2021, which was recognized in Other Operating Expenses on the FirstEnergy Consolidated
Statements of Income. This $21 million charge reflects the difference between amounts originally recorded as regulatory assets
and amounts which will ultimately be recovered as a result of the pending settlement. From a segment perspective, during the
third quarter of 2021, the Regulated Transmission segment recorded a pre-tax charge of $48 million and the Regulated
Distribution segment recognized a $27 million reduction to a reserve previously recorded in 2010. In addition, the settlement
provides for partial recovery of future incurred costs allocated to ATSI by MISO for the above-referenced transmission projects
that were constructed by other MISO transmission owners, which is not expected to have a material impact on FirstEnergy or
ATSI. The uncontested settlement is pending before FERC for approval.
FERC Actions on Tax Act
On March 15, 2018, FERC initiated proceedings on the question of how to address possible changes to ADIT and bonus
depreciation as a result of the Tax Act. Such possible changes could impact FERC-jurisdictional rates, including transmission
rates. On November 21, 2019, FERC issued a final rule (Order No. 864). Order No. 864 requires utilities with transmission
formula rates to update their formula rate templates to include mechanisms to: (i) deduct any excess ADIT from or add any
deficient ADIT to their rate base; (ii) raise or lower their income tax allowances by any amortized excess or deficient ADIT; and
(iii) incorporate a new permanent worksheet into their rates that will annually track information related to excess or deficient ADIT.
Per FERC directives, ATSI submitted its compliance filing on May 1, 2020. MAIT submitted its compliance filing on June 1, 2020.
On November 18, 2021, FERC issued an order that: (i) accepted ATSI proposed tariff amendments to its rate base adjustment
mechanism, effective January 27, 2020; (ii) directed ATSI to make a further compliance filing by January 17, 2022; and (iii) set
the amount of ATSI’s recorded ADIT balances as of December 31, 2017, for hearing and settlement procedures. ATSI submitted
the compliance filing, and is participating in settlement negotiations. On December 3, 2021, FERC issued an order that (i)
accepted MAIT’s proposed tariff amendments to its rate base adjustment mechanism, effective January 27, 2020; (ii) directed
MAIT to make a further compliance filing by February 1, 2022; and (iii) set the amount of MAIT’s recorded ADIT balances as of
December 31, 2017 for hearing and settlement procedures. MAIT submitted the compliance filing, and is participating in
settlement negotiations. On May 15, 2020, TrAIL submitted its compliance filing and on June 1, 2020, PATH submitted its
required compliance filing. On May 4, 2021, FERC staff requested additional information about PATH’s proposed rate base
adjustment mechanism, and PATH submitted the requested information on June 3, 2021. On July 12, 2021, FERC staff
requested additional information about TrAIL’s proposed rate base adjustment mechanism. TrAIL filed its response on August 6,
2021. The PATH and TrAIL compliance filings each remain pending before FERC. MP, WP and PE (as holders of a “stated”
transmission rate when Order No. 864 issued) are addressing these requirements in the transmission formula rates amendments
that were filed on October 29, 2020, and which have been accepted by FERC effective January 1, 2021, subject to refund,
pending further hearing and settlement procedures, MP, WP and PE are engaged in settlement negotiations with other parties to
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this proceeding. JCP&L addressed these requirements as part of its transmission formula rate case, which was resolved by a
settlement approved by FERC on April 15, 2021.
Transmission ROE Methodology
On May 20, 2021, in a case not involving FirstEnergy, FERC issued Opinion No. 575 in which it reiterated the nationwide ROE
methodology set forth in 2020 in Opinion Nos. 569-A and 569-B. Under this methodology, FERC employs three financial models
– discounted cash flow, capital-asset pricing, and risk premium – to calculate a composite zone of reasonableness. As it has
done in other recent ROE cases, FERC rejected the use of the expected earnings methodology in calculating the authorized
ROE. A request for clarification or, alternatively, rehearing of Opinion No. 575 was filed on June 21, 2021, and on September 9,
2021, FERC issued an order clarifying aspects of its prior opinion, but affirming the result. On July 15, 2021, FERC issued
another order, addressing ROE for a generation company in New England, which applied a standard consistent with Opinion
Nos. 569-A and 569-B. FERC’s Opinion Nos. 569-A and 569-B, upon which Opinion No. 575 is based, have been appealed to
the D.C. Circuit. FirstEnergy is not participating in the appeal. Any changes to FERC’s transmission rate ROE and incentive
policies for transmission rates would be applied on a prospective basis.
On March 20, 2020, FERC initiated a rulemaking proceeding on the transmission rate incentives provisions of Section 219 of the
2005 Energy Policy Act. FirstEnergy submitted comments through EEI and as part of a consortium of PJM Transmission Owners.
In a supplemental rulemaking proceeding that was initiated on April 15, 2021, FERC requested comments on, among other
things, whether to require utilities that have been members of an RTO for three years or more and that have been collecting an
“RTO membership” ROE incentive adder to file tariff updates that would terminate collection of the incentive adder. Initial
comments on the proposed rule were filed on June 25, 2021, and reply comments were filed on July 26, 2021. The rulemaking
remains pending before FERC. FirstEnergy is a member of PJM and its transmission subsidiaries could be affected by the
supplemental proposed rule. FirstEnergy participated in comments that were submitted by a group of PJM transmission owners
and by various industry trade groups. If there were to be any changes to FirstEnergy transmission incentive ROE, such changes
will be applied on a prospective basis.
JCP&L Transmission Formula Rate
On October 30, 2019, JCP&L filed tariff amendments with FERC to convert JCP&L’s existing stated transmission rate to a
forward-looking formula transmission rate. JCP&L requested that the tariff amendments become effective January 1, 2020. On
December 19, 2019, FERC issued its initial order in the case, allowing JCP&L to transition to a forward-looking formula rate as of
January 1, 2020 as requested, subject to refund, pending further hearing and settlement proceedings. JCP&L and the parties to
the FERC proceeding subsequently were able to reach settlement, and on February 2, 2021, JCP&L filed an offer of settlement
with FERC. On April 15, 2021, FERC approved the settlement agreement as filed, with no changes, effective January 1, 2021.
Allegheny Power Zone Transmission Formula Rate Filings
On October 29, 2020, MP, PE and WP filed tariff amendments with FERC to implement a forward-looking formula transmission
rate, to be effective January 1, 2021. In addition, on October 30, 2020, KATCo filed a proposed new tariff to establish a forward-
looking formula rate and requested that the new rate become effective January 1, 2021. In its filing, KATCo explained that while it
currently owns no transmission assets, it may build new transmission facilities in the Allegheny zone, and that it may seek
required state and federal authorizations to acquire transmission assets from PE and WP by January 1, 2022. These
transmission rate filings were accepted for filing by FERC on December 31, 2020, effective January 1, 2021, subject to refund,
pending further hearing and settlement procedures and were consolidated into a single proceeding. MP, PE and WP, and KATCo
are engaged in settlement negotiations with the other parties to the formula rate proceedings. KATCo will be included in the
Regulated Transmission reportable segment.
13. COMMITMENTS, GUARANTEES AND CONTINGENCIES
GUARANTEES AND OTHER ASSURANCES
FirstEnergy has various financial and performance guarantees and indemnifications which are issued in the normal course of
business. These contracts include performance guarantees, stand-by letters of credit, debt guarantees, surety bonds and
indemnifications. FirstEnergy enters into these arrangements to facilitate commercial transactions with third parties by enhancing
the value of the transaction to the third party.
As of December 31, 2021, outstanding guarantees and other assurances aggregated approximately $1.1 billion, consisting of
parental guarantees on behalf of its consolidated subsidiaries ($0.6 billion) and other assurances ($0.5 billion).
COLLATERAL AND CONTINGENT-RELATED FEATURES
In the normal course of business, FE and its subsidiaries may enter into physical or financially settled contracts for the sale and
purchase of electric capacity, energy, fuel and emission allowances. Certain agreements contain provisions that require FE or its
subsidiaries to post collateral. This collateral may be posted in the form of cash or credit support with thresholds contingent upon
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FE's or its subsidiaries' credit rating from each of the major credit rating agencies. The collateral and credit support requirements
vary by contract and by counterparty.
As of December 31, 2021, $55 million of collateral has been posted by FE or its subsidiaries and is included in Prepaid taxes and
other current assets on FirstEnergy's Consolidated Balance Sheets.
These credit-risk-related contingent features stipulate that if the subsidiary were to be downgraded or lose its investment grade
credit rating (based on its senior unsecured debt rating), it would be required to provide additional collateral. The following table
discloses the potential additional credit rating contingent contractual collateral obligations as of December 31, 2021:
Potential Collateral Obligations
Contractual Obligations for Additional Collateral
Upon Further Downgrade
Surety Bonds (collateralized amount)(1)
Total Exposure from Contractual Obligations
Utilities
and FET
FE
(In millions)
Total
$
$
44 $
57
— $
258
101 $
258 $
44
315
359
(1) Surety Bonds are not tied to a credit rating. Surety Bonds' impact assumes maximum contractual obligations, which is
ordinarily 100% of the face amount of the surety bond except with respect to $39 million of surety obligations for which the
collateral obligation is capped at 60% of the face amount, and typical obligations require 30 days to cure.
OTHER COMMITMENTS AND CONTINGENCIES
FE was previously a guarantor under a $120 million syndicated senior secured term loan facility due November 12, 2024, which
Global Holding repaid during the fourth quarter of 2021, and as a result, FirstEnergy’s guarantee is no longer in effect.
ENVIRONMENTAL MATTERS
Various federal, state and local authorities regulate FirstEnergy with regard to air and water quality, hazardous and solid waste
disposal, and other environmental matters. While FirstEnergy’s environmental policies and procedures are designed to achieve
compliance with applicable environmental laws and regulations, such laws and regulations are subject to periodic review and
potential revision by the implementing agencies. FirstEnergy cannot predict the timing or ultimate outcome of any of these
reviews or how any future actions taken as a result thereof may materially impact its business, results of operations, cash flows
and financial condition.
Clean Air Act
FirstEnergy complies with SO2 and NOx emission reduction requirements under the CAA and SIP(s) by burning lower-sulfur fuel,
utilizing combustion controls and post-combustion controls and/or using emission allowances.
CSAPR requires reductions of NOx and SO2 emissions in two phases (2015 and 2017), ultimately capping SO2 emissions in
affected states to 2.4 million tons annually and NOx emissions to 1.2 million tons annually. CSAPR allows trading of NOx and
SO2 emission allowances between power plants located in the same state and interstate trading of NOx and SO2 emission
allowances with some restrictions. On July 28, 2015, the D.C. Circuit ordered the EPA to reconsider the CSAPR caps on NOx
and SO2 emissions from power plants in 13 states, including West Virginia. This followed the 2014 U.S. Supreme Court ruling
generally upholding the EPA’s regulatory approach under CSAPR but questioning whether the EPA required upwind states to
reduce emissions by more than their contribution to air pollution in downwind states. The EPA issued a CSAPR Update on
September 7, 2016, reducing summertime NOx emissions from power plants in 22 states in the eastern U.S., including West
Virginia, beginning in 2017. Various states and other stakeholders appealed the CSAPR Update to the D.C. Circuit in November
and December 2016. On September 13, 2019, the D.C. Circuit remanded the CSAPR Update to the EPA citing that the rule did
not eliminate upwind states’ significant contributions to downwind states’ air quality attainment requirements within applicable
attainment deadlines.
Also, during this time, in March 2018, the State of New York filed a CAA Section 126 petition with the EPA alleging that NOx
emissions from nine states (including West Virginia) significantly contribute to New York’s inability to attain the ozone NAAQS.
The petition sought suitable emission rate limits for large stationary sources that are allegedly affecting New York’s air quality
within the three years allowed by CAA Section 126. On September 20, 2019, the EPA denied New York’s CAA Section 126
petition. On October 29, 2019, the State of New York appealed the denial of its petition to the D.C. Circuit. On July 14, 2020, the
D.C. Circuit reversed and remanded the New York petition to the EPA for further consideration. On March 15, 2021, the EPA
issued a revised CSAPR Update that addresses, among other things, the remands of the CSAPR Update and the New York
Section 126 Petition. Depending on the outcome of any appeals and how the EPA and the states ultimately implement the
revised CSAPR Update, the future cost of compliance may materially impact FirstEnergy's operations, cash flows and financial
condition.
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In February 2019, the EPA announced its final decision to retain without changes the NAAQS for SO2, specifically retaining the
2010 primary (health-based) 1-hour standard of 75 PPB. As of March 31, 2020, FirstEnergy has no power plants operating in
areas designated as non-attainment by the EPA.
Climate Change
There are several initiatives to reduce GHG emissions at the state, federal and international level. Certain northeastern states
are participating in the RGGI and western states led by California, have implemented programs, primarily cap and trade
mechanisms, to control emissions of certain GHGs. Additional policies reducing GHG emissions, such as demand reduction
programs, renewable portfolio standards and renewable subsidies have been implemented across the nation.
In September 2016, the U.S. joined in adopting the agreement reached on December 12, 2015, at the United Nations Framework
Convention on Climate Change meetings in Paris to reduce GHGs. The Paris Agreement’s non-binding obligations to limit global
warming to below two degrees Celsius became effective on November 4, 2016. On June 1, 2017, the Trump Administration
announced that the U.S. would cease all participation in the Paris Agreement. On January 20, 2021, President Biden signed an
executive order re-adopting the agreement on behalf of the U.S. In November 2020, FirstEnergy published its Climate Story
which includes its climate position and strategy, as well as a new comprehensive and ambitious GHG emission goal. FirstEnergy
pledged to achieve carbon neutrality by 2050 and set an interim goal for a 30% reduction in GHGs within FirstEnergy’s direct
operational control by 2030, based on 2019 levels. Future resource plans to achieve carbon reductions, including any
determination of retirement dates of the regulated coal-fired generation, will be developed by working collaboratively with
regulators in West Virginia. Determination of the useful life of the regulated coal-fired generation could result in changes in
depreciation, and/or continued collection of net plant in rates after retirement, securitization, sale, impairment, or regulatory
disallowances. If MP is unable to recover these costs, it could have a material adverse effect on FirstEnergy’s and/or MP’s
financial condition, results of operations, and cash flow. Furthermore, FirstEnergy cannot currently estimate the financial impact
of climate change policies, although potential legislative or regulatory programs restricting CO2 emissions, or litigation alleging
damages from GHG emissions, could require material capital and other expenditures or result in changes to its operations.
In December 2009, the EPA released its final “Endangerment and Cause or Contribute Findings for GHGs under the Clean Air
Act,” concluding that concentrations of several key GHGs constitute an "endangerment" and may be regulated as "air pollutants"
under the CAA and mandated measurement and reporting of GHG emissions from certain sources, including electric generating
plants. Subsequently, the EPA released its final CPP regulations in August 2015 to reduce CO2 emissions from existing fossil
fuel-fired EGUs and finalized separate regulations imposing CO2 emission limits for new, modified, and reconstructed fossil fuel-
fired EGUs. Numerous states and private parties filed appeals and motions to stay the CPP with the D.C. Circuit in October
2015. On February 9, 2016, the U.S. Supreme Court stayed the rule during the pendency of the challenges to the D.C. Circuit
and U.S. Supreme Court. On March 28, 2017, an executive order, entitled “Promoting Energy Independence and Economic
Growth,” instructed the EPA to review the CPP and related rules addressing GHG emissions and suspend, revise or rescind the
rules if appropriate. On June 19, 2019, the EPA repealed the CPP and replaced it with the ACE rule that established guidelines
for states to develop standards of performance to address GHG emissions from existing coal-fired generation. On January 19,
2021, the D.C. Circuit vacated and remanded the ACE rule declaring that the EPA was “arbitrary and capricious” in its rule
making and, as such, the ACE rule is no longer in effect and all actions thus far taken by states to implement the federally
mandated rule are now null and void. The D.C. Circuit decision is subject to legal challenge. Depending on the outcomes of
further appeals and how any final rules are ultimately implemented, the future cost of compliance may be material.
Clean Water Act
Various water quality regulations, the majority of which are the result of the federal CWA and its amendments, apply to
FirstEnergy’s facilities. In addition, the states in which FirstEnergy operates have water quality standards applicable to
FirstEnergy’s operations.
On September 30, 2015, the EPA finalized new, more stringent effluent limits for the Steam Electric Power Generating category
(40 CFR Part 423) for arsenic, mercury, selenium and nitrogen for wastewater from wet scrubber systems and zero discharge of
pollutants in ash transport water. The treatment obligations were to phase-in as permits are renewed on a five-year cycle from
2018 to 2023. However, on April 13, 2017, the EPA granted a Petition for Reconsideration and on September 18, 2017, the EPA
postponed certain compliance deadlines for two years. On August 31, 2020, the EPA issued a final rule revising the effluent limits
for discharges from wet scrubber systems, retaining the zero-discharge standard for ash transport water, (with some limited
discharge allowances), and extending the deadline for compliance to December 31, 2025 for both. In addition, the EPA allows for
less stringent limits for sub-categories of generating units based on capacity utilization, flow volume from the scrubber system,
and unit retirement date. The EPA is reconsidering the ELG rule with a publicly announced target of issuing a proposed revised
rule in the Fall of 2022 and a final rule by the Spring of 2023. In the interim, the rule issued on August 31, 2020, remains in effect.
Depending on the outcome of appeals and how final rules are ultimately implemented, the compliance with these standards,
could require additional capital expenditures or changes in operations at Ft. Martin and Harrison power stations from what was
filed with the WVPSC in December 2021 that seeks approval of environmental compliance projects to comply with the EPA’s
ELG.
103
After the completion of a negotiated settlement, a complaint was filed by the EPA and PA DEP on January 10, 2022 in Federal
District Court for the Western District of Pennsylvania, alleging, among other things, that WP violated the CWA in connection with
past boron exceedances at WP’s Springdale and Mingo landfills. On January 11, 2022, WP entered into a consent decree with
the EPA and PA DEP resolving the matters addressed in the complaint, which, among other things, requires a civil penalty of
$610 thousand. The consent decree is subject to final approval by the District Court pending public comment.
Regulation of Waste Disposal
Federal and state hazardous waste regulations have been promulgated as a result of the RCRA, as amended, and the Toxic
Substances Control Act. Certain CCRs, such as coal ash, were exempted from hazardous waste disposal requirements pending
the EPA’s evaluation of the need for future regulation.
In April 2015, the EPA finalized regulations for the disposal of CCRs (non-hazardous), establishing national standards for landfill
design, structural integrity design and assessment criteria for surface impoundments, groundwater monitoring and protection
procedures and other operational and reporting procedures to assure the safe disposal of CCRs from electric generating plants.
On September 13, 2017, the EPA announced that it would reconsider certain provisions of the final regulations. On July 29,
2020, the EPA published a final rule again revising the date that certain CCR impoundments must cease accepting waste and
initiate closure to April 11, 2021. The final rule also allows for an extension of the closure deadline based on meeting proscribed
site-specific criteria. On November 30, 2020, AE Supply submitted a closure deadline extension request to the EPA seeking to
extend the closure date of McElroy's Run CCR impoundment facility until 2024, which request is pending technical review by the
EPA. AE Supply continues to operate McElroy’s Run as a disposal facility for FG’s Pleasants Power Station.
FE or its subsidiaries have been named as potentially responsible parties at waste disposal sites, which may require cleanup
under the CERCLA. Allegations of disposal of hazardous substances at historical sites and the liability involved are often
unsubstantiated and subject to dispute; however, federal law provides that all potentially responsible parties for a particular site
may be liable on a joint and several basis. Environmental liabilities that are considered probable have been recognized on the
Consolidated Balance Sheets as of December 31, 2021, based on estimates of the total costs of cleanup, FirstEnergy’s
proportionate responsibility for such costs and the financial ability of other unaffiliated entities to pay. Total liabilities of
approximately $105 million have been accrued through December 31, 2021, of which, approximately $70 million are for
environmental remediation of former MGP and gas holder facilities in New Jersey, which are being recovered by JCP&L through
a non-bypassable SBC. FE or its subsidiaries could be found potentially responsible for additional amounts or additional sites,
but the loss or range of losses cannot be determined or reasonably estimated at this time.
OTHER LEGAL PROCEEDINGS
United States v. Larry Householder, et al.
On July 21, 2020, a complaint and supporting affidavit containing federal criminal allegations were unsealed against the now
former Ohio House Speaker Larry Householder and other individuals and entities allegedly affiliated with Mr. Householder. Also,
on July 21, 2020, and in connection with the investigation, FirstEnergy received subpoenas for records from the U.S. Attorney’s
Office for the S.D. Ohio. FirstEnergy was not aware of the criminal allegations, affidavit or subpoenas before July 21, 2020.
On July 21, 2021, FE entered into a three-year DPA with the U.S. Attorney’s Office that, subject to court proceedings, resolves
this matter. Under the DPA, FE has agreed to the filing of a criminal information charging FE with one count of conspiracy to
commit honest services wire fraud. The DPA requires that FirstEnergy, among other obligations: (i) continue to cooperate with the
U.S. Attorney’s Office in all matters relating to the conduct described in the DPA and other conduct under investigation by the
U.S. government; (ii) pay a criminal monetary penalty totaling $230 million within sixty days, which shall consist of (x) $115
million paid by FE to the United States Treasury and (y) $115 million paid by FE to the ODSA to fund certain assistance
programs, as determined by the ODSA, for the benefit of low-income Ohio electric utility customers; (iii) publish a list of all
payments made in 2021 to either 501(c)(4) entities or to entities known by FirstEnergy to be operating for the benefit of a public
official, either directly or indirectly, and update the same on a quarterly basis during the term of the DPA; (iv) issue a public
statement, as dictated in the DPA, regarding FE’s use of 501(c)(4) entities; and (v) continue to implement and review its
compliance and ethics program, internal controls, policies and procedures designed, implemented and enforced to prevent and
detect violations of the U.S. laws throughout its operations, and to take certain related remedial measures. The $230 million
payment will neither be recovered in rates or charged to FirstEnergy customers nor will FirstEnergy seek any tax deduction
related to such payment. The entire amount of the monetary penalty was recognized as expense in the second quarter of 2021,
and paid in the third quarter of 2021. Under the terms of the DPA, the criminal information will be dismissed after FirstEnergy fully
complies with its obligations under the DPA.
Legal Proceedings Relating to United States v. Larry Householder, et al.
On August 10, 2020, the SEC, through its Division of Enforcement, issued an order directing an investigation of possible
securities laws violations by FE, and on September 1, 2020, issued subpoenas to FE and certain FE officers. On April 28, 2021,
the SEC issued an additional subpoena to FE. While no contingency has been reflected in its consolidated financial statements,
FE believes that it is probable that it will incur a loss in connection with the resolution of the SEC investigation. Given the ongoing
104
nature and complexity of the review, inquiries and investigations, FE cannot yet reasonably estimate a loss or range of loss that
may arise from the resolution of the SEC investigation.
In addition to the subpoenas referenced above under “—United States v. Larry Householder, et. al.” and the SEC investigation,
certain FE stockholders and FirstEnergy customers filed several lawsuits against FirstEnergy and certain current and former
directors, officers and other employees, and the complaints in each of these suits is related to allegations in the complaint and
supporting affidavit relating to HB 6 and the now former Ohio House Speaker Larry Householder and other individuals and
entities allegedly affiliated with Mr. Householder. The plaintiffs in each of the below cases seek, among other things, to recover
an unspecified amount of damages (unless otherwise noted). Unless otherwise indicated, no contingency has been reflected in
FirstEnergy’s consolidated financial statements with respect to these lawsuits as a loss is neither probable, nor is a loss or range
of a loss reasonably estimable.
•
In re FirstEnergy Corp. Securities Litigation (Federal District Court, S.D. Ohio); on July 28, 2020 and August 21, 2020,
purported stockholders of FE filed putative class action lawsuits alleging violations of the federal securities laws. Those
actions have been consolidated and a lead plaintiff, the Los Angeles County Employees Retirement Association, has
been appointed by the court. A consolidated complaint was filed on February 26, 2021. The consolidated complaint
alleges, on behalf of a proposed class of persons who purchased FE securities between February 21, 2017 and July 21,
2020, that FE and certain current or former FE officers violated Sections 10(b) and 20(a) of the Exchange Act by issuing
misrepresentations or omissions concerning FE’s business and results of operations. The consolidated complaint also
alleges that FE, certain current or former FE officers and directors, and a group of underwriters violated Sections 11,
12(a)(2) and 15 of the Securities Act of 1933 as a result of alleged misrepresentations or omissions in connection with
offerings of senior notes by FE in February and June 2020. FE believes that it is probable that it will incur a loss in
connection with the resolution of this lawsuit. Given the ongoing nature and complexity of such litigation, FE cannot yet
reasonably estimate a loss or range of loss.
•
• MFS Series Trust I, et al. v. FirstEnergy Corp., et al. (Federal District Court, S.D. Ohio) on December 17, 2021,
purported stockholders of FE filed a complaint against FE, certain current and former officers, and certain current and
former officers of EH. The complaint alleges that the defendants violated Sections 10(b) and 20(a) of the Exchange Act
by issuing alleged misrepresentations or omissions regarding FE’s business and its results of operations, and seeks the
same relief as the In re FirstEnergy Corp. Securities Litigation described above. FE believes that it is probable that it will
incur a loss in connection with the resolution of this lawsuit. Given the ongoing nature and complexity of such litigation,
FE cannot yet reasonably estimate a loss or range of loss.
State of Ohio ex rel. Dave Yost, Ohio Attorney General v. FirstEnergy Corp., et al. and City of Cincinnati and City of
Columbus v. FirstEnergy Corp. (Common Pleas Court, Franklin County, OH, all actions have been consolidated); on
September 23, 2020 and October 27, 2020, the OAG and the cities of Cincinnati and Columbus, respectively, filed
complaints against several parties including FE (the OAG also named FES as a defendant), each alleging civil
violations of the Ohio Corrupt Activity Act in connection with the passage of HB 6. On January 13, 2021, the OAG filed a
motion for a temporary restraining order and preliminary injunction against FirstEnergy seeking to enjoin FirstEnergy
from collecting the Ohio Companies' decoupling rider. On January 31, 2021, FE reached a partial settlement with the
OAG and the cities of Cincinnati and Columbus with respect to the temporary restraining order and preliminary
injunction request and related issues. In connection with the partial settlement, the Ohio Companies filed an application
on February 1, 2021, with the PUCO to set their respective decoupling riders (CSR) to zero. On February 2, 2021, the
PUCO approved the application of the Ohio Companies setting the rider to zero and no additional customer bills will
include new decoupling rider charges after February 8, 2021. The cases are stayed pending final resolution of the
United States v. Larry Householder, et al. criminal proceeding described above, although on August 13, 2021, new
defendants were added to the complaint, including two former officers of FirstEnergy. On November 9, 2021, the OAG
filed a motion to lift the agreed-upon stay, which FE opposed on November 19, 2021; the motion remains pending. On
December 2, 2021, the cities and FE entered a stipulated dismissal with prejudice of the cities’ suit.
Smith v. FirstEnergy Corp. et al., Buldas v. FirstEnergy Corp. et al., and Hudock and Cameo Countertops, Inc. v.
FirstEnergy Corp. et al. (Federal District Court, S.D. Ohio, all actions have been consolidated); on July 27, 2020, July
31, 2020, and August 5, 2020, respectively, purported customers of FE filed putative class action lawsuits against FE
and FESC, as well as certain current and former FE officers, alleging civil Racketeer Influenced and Corrupt
Organizations Act violations and related state law claims. The court denied FE’s motions to dismiss and stay discovery
on February 10 and 11, 2021, respectively, and the defendants submitted answers to the complaint on March 10, 2021.
The plaintiffs moved to certify the case as a class action on June 28, 2021, and moved for leave to amend the complaint
to add FES as a defendant on September 27, 2021. The court granted the motion to amend on November 10, 2021. On
November 9, 2021, the court issued an order granting Plaintiffs' motion for class certification, but vacated that order on
November 19, 2021, to allow defendants to take the named plaintiffs’ depositions and to file an opposition to the motion,
which they filed on December 14, 2021. On November 19, 2021, FE and FESC moved for judgment on the pleadings.
One of the individual defendants moved to dismiss the amended complaint on November 24, 2021. On December 28,
2021, the parties jointly moved the court to stay consideration of the pending motions for class certification, to dismiss,
and for judgment on the pleadings for 45 days. The court granted the motion on December 29, 2021, and the cases are
currently stayed. FE is engaged with the parties in settlement discussions, and believes that it is probable that it will
incur a loss in connection with the resolution of these lawsuits. As a result, FirstEnergy recognized in the fourth quarter
of 2021 a pre-tax reserve of $37.5 million in the aggregate with respect to these lawsuits and the Emmons lawsuit
below.
•
105
•
Emmons v. FirstEnergy Corp. et al. (Common Pleas Court, Cuyahoga County, OH); on August 4, 2020, a purported
customer of FirstEnergy filed a putative class action lawsuit against FE, FESC, the Ohio Companies, along with FES,
alleging several causes of action, including negligence and/or gross negligence, breach of contract, unjust enrichment,
and unfair or deceptive consumer acts or practices. On October 1, 2020, plaintiffs filed a First Amended Complaint,
adding as a plaintiff a purported customer of FirstEnergy and alleging a civil violation of the Ohio Corrupt Activity Act
and civil conspiracy against FE, FESC and FES. On May 4, 2021, the court granted the defendants’ motion to dismiss
plaintiffs’ breach of contract claims and denied the remainder of the motions to dismiss. The defendants submitted
answers to the complaint on June 1, 2021. Discovery is proceeding. On December 30, 2021, the plaintiff filed a Second
Amended Complaint removing one of the named plaintiffs and updating the class definition. FE is engaged with the
parties in settlement discussions, and believes that it is probable that it will incur a loss in connection with the resolution
of these lawsuits. As a result, FirstEnergy recognized in the fourth quarter of 2021 a pre-tax reserve of $37.5 million in
the aggregate with respect to this lawsuit and the lawsuits above consolidated with Smith in the S.D. Ohio alleging,
among other things, civil violations of the Racketeer Influenced and Corrupt Organizations Act.
On February 9, 2022, FE, acting through the SLC, agreed to a settlement term sheet to resolve the following shareholder
derivative lawsuits relating to HB 6 and the now former Ohio House Speaker Larry Householder and other individuals and
entities allegedly affiliated with Mr. Householder that were filed in the S.D. Ohio, the N.D. Ohio, and the Ohio Court of Common
Pleas, Summit County:
•
Gendrich v. Anderson, et al. and Sloan v. Anderson, et al. (Common Pleas Court, Summit County, OH, all actions have
been consolidated); on July 26, 2020 and July 31, 2020, respectively, purported stockholders of FE filed shareholder
derivative action lawsuits against certain FE directors and officers, alleging, among other things, breaches of fiduciary
duty.
• Miller v. Anderson, et al. (Federal District Court, N.D. Ohio); Bloom, et al. v. Anderson, et al.; Employees Retirement
System of the City of St. Louis v. Jones, et al.; Electrical Workers Pension Fund, Local 103, I.B.E.W. v. Anderson et al.;
Massachusetts Laborers Pension Fund v. Anderson et al.; The City of Philadelphia Board of Pensions and Retirement
v. Anderson et al.; Atherton v. Dowling et al.; Behar v. Anderson, et al. (Federal District Court, S.D. Ohio, all actions
have been consolidated); beginning on August 7, 2020, purported stockholders of FE filed shareholder derivative
actions alleging the FE Board and officers breached their fiduciary duties and committed violations of Section 14(a) of
the Exchange Act.
The proposed settlement, which is subject to court approval, will fully resolve the shareholder derivative lawsuits above and
stipulates a series of corporate governance enhancements, that is expected to result in the following:
•
•
•
•
•
•
Six members of the FE Board, Messrs. Michael J. Anderson, Donald T. Misheff, Thomas N. Mitchell, Christopher D.
Pappas and Luis A. Reyes, and Ms. Julia L. Johnson will not stand for re-election at FE’s 2022 annual shareholder
meeting;
A special FE Board committee of at least three recently appointed independent directors will be formed to initiate a
review process of the current senior executive team, to begin within 30 days of the 2022 annual shareholder meeting;
The FE Board will oversee FE’s lobbying and political activities, including periodically reviewing and approving political
and lobbying action plans prepared by management;
The FE Board will form another committee of recently appointed independent directors to oversee the implementation
and third-party audits of the FE Board-approved action plans with respect to political and lobbying activities;
FE will implement enhanced disclosure to shareholders of political and lobbying activities, including enhanced
disclosure in its annual proxy statement; and
FE will further align financial incentives of senior executives to proactive compliance with legal and ethical obligations.
The settlement also includes a payment to FirstEnergy of $180 million, to be paid by insurance after court approval, less any
court-ordered attorney’s fees awarded to plaintiffs.
In letters dated January 26, and February 22, 2021, staff of FERC's Division of Investigations notified FirstEnergy that the
Division is conducting an investigation of FirstEnergy’s lobbying and governmental affairs activities concerning HB 6, and staff
directed FirstEnergy to preserve and maintain all documents and information related to the same as such have been developed
as part of an ongoing non-public audit being conducted by FERC's Division of Audits and Accounting. While no contingency has
been reflected in the consolidated financial statements, FirstEnergy believes that it is probable that it will incur a loss in
connection with the resolution of the FERC investigation. Given the ongoing nature and complexity of the review, inquiries and
investigations, FirstEnergy cannot yet reasonably estimate a loss or range of loss that may arise from the resolution of the FERC
investigation.
The outcome of any of these lawsuits, governmental investigations and audit is uncertain and could have a material adverse
effect on FE’s or its subsidiaries’ reputation, business, financial condition, results of operations, liquidity, and cash flows.
106
Other Legal Matters
There are various lawsuits, claims (including claims for asbestos exposure) and proceedings related to FirstEnergy’s normal
business operations pending against FE or its subsidiaries. The loss or range of loss in these matters is not expected to be
material to FE or its subsidiaries. The other potentially material items not otherwise discussed above are described under Note
12, “Regulatory Matters.”
FirstEnergy accrues legal liabilities only when it concludes that it is probable that it has an obligation for such costs and can
reasonably estimate the amount of such costs. In cases where FirstEnergy determines that it is not probable, but reasonably
possible that it has a material obligation, it discloses such obligations and the possible loss or range of loss if such estimate can
be made. If it were ultimately determined that FE or its subsidiaries have legal liability or are otherwise made subject to liability
based on any of the matters referenced above, it could have a material adverse effect on FE’s or its subsidiaries’ financial
condition, results of operations and cash flows.
14. DISCONTINUED OPERATIONS
On March 31, 2018, the FES Debtors announced that, in order to facilitate an orderly financial restructuring, they filed voluntary
petitions under Chapter 11 of the United States Bankruptcy Code with the Bankruptcy Court. On February 27, 2020, the FES
Debtors effectuated their plan, emerged from bankruptcy and FirstEnergy tendered the bankruptcy court approved settlement
payments totaling $853 million and a $125 million tax sharing payment to the FES Debtors. The FES Bankruptcy settlement was
conditioned on the FES Debtors confirming and effectuating a plan of reorganization acceptable to FirstEnergy.
As contemplated under the FES Bankruptcy settlement agreement, AE Supply entered into an agreement on December 31,
2018, to transfer the 1,300 MW Pleasants Power Station and related assets to FG, while retaining certain specified liabilities.
Under the terms of the agreement, FG acquired the economic interests in Pleasants as of January 1, 2019, and AE Supply
operated Pleasants until ownership was transferred on January 30, 2020. AE Supply will continue to provide access to the
McElroy's Run CCR impoundment facility, which was not transferred, and FE will provide guarantees for certain retained
environmental liabilities of AE Supply, including the McElroy’s Run CCR impoundment facility. During the first quarter of 2020, FG
paid AE Supply approximately $65 million of cash for related materials and supplies (at book value) and the settlement of FG’s
economic interest in Pleasants.
By eliminating a significant portion of its competitive generation fleet with the deconsolidation of the FES Debtors, FirstEnergy
has concluded the FES Debtors meet the criteria for discontinued operations, as this represents a significant event in
management’s strategic review to exit commodity-exposed generation and transition to a fully regulated company.
Income Taxes
As a result of the FES Debtors’ tax return deconsolidation, FirstEnergy recognized a worthless stock deduction, of approximately
$4.9 billion, net of unrecognized tax benefits of $316 million, for the remaining tax basis in the stock of the FES Debtors. Based
upon completion of the IRS’s review of the 2020 federal income tax return during fourth quarter 2021, FirstEnergy recognized the
full tax benefit of the worthless stock deduction of approximately $5.2 billion, or $1.1 billion on a tax-effected basis, net of
valuation allowances recorded against the state tax benefit ($21 million), eliminating associated uncertain tax position reserves.
Upon emergence, FirstEnergy paid the FES Debtors $125 million to settle all reconciliations under the Intercompany Tax
Allocation Agreement for 2018, 2019 and 2020 tax years, including all issues regarding nondeductible interest.
In conjunction with filing the 2020 consolidated federal income tax return during the third quarter of 2021, FirstEnergy computed
a final federal NOL allocation between the FES Debtors and FirstEnergy consolidated that resulted in FirstEnergy recording an
increase to the consolidated NOL carryforward of approximately $289 million ($61 million tax-effected).
107
Summarized Results of Discontinued Operations
Summarized results of discontinued operations for the years ended December 31, 2021, 2020, and 2019 were as follows:
(In millions)
Revenues
Fuel
Other operating expenses
General taxes
Pleasants economic interest(1)
Other expense, net
Loss from discontinued operations, before tax
Income tax expense (benefit)
Loss from discontinued operations, net of tax
Settlement consideration and services credit
Accelerated net pension and OPEB prior service credits
Gain on disposal of FES and FENOC, before tax
Income tax benefits, including worthless stock deduction
Gain on disposal of FES and FENOC, net of tax
For the Years Ended December 31,
2020
2021
2019
$
— $
—
—
—
—
(4)
(4)
(1)
(3)
—
—
—
(47)
47
7 $
(6)
(6)
—
5
—
—
—
—
(1)
18
17
(59)
76
188
(140)
(63)
(14)
27
(2)
(4)
47
(51)
7
—
7
(52)
59
Income from discontinued operations
$
44 $
76 $
8
(1) Reflects the estimated amounts owed from FG for its economic interests in Pleasants effective January 1, 2019. As discussed above,
settlement of the economic interests occurred during the first quarter of 2020.
FirstEnergy's Consolidated Statements of Cash Flows combines cash flows from discontinued operations with cash flows from
continuing operations within each cash flow category. The following table summarizes the major classes of cash flow items from
discontinued operations for the years ended December 31, 2021, 2020 and 2019:
(In millions)
CASH FLOWS FROM OPERATING ACTIVITIES:
Income from discontinued operations
Gain on disposal, net of tax
Deferred income taxes and investment tax credits, net
15. SEGMENT INFORMATION
For the Years Ended
December 31,
2020
2019
2021
$
44 $
76 $
(47)
—
(76)
—
8
(59)
47
FE and its subsidiaries are principally involved in the transmission, distribution and generation of electricity through its reportable
segments, Regulated Distribution and Regulated Transmission.
The Regulated Distribution segment distributes electricity through FirstEnergy’s ten utility operating companies, serving
approximately six million customers within 65,000 square miles of Ohio, Pennsylvania, West Virginia, Maryland, New Jersey and
New York, and purchases power for its POLR, SOS, SSO and default service requirements in Ohio, Pennsylvania, New Jersey,
and Maryland. This segment also controls 3,580 MWs of regulated electric generation capacity located primarily in West Virginia
and Virginia. The segment's results reflect the costs of securing and delivering electric generation from transmission facilities to
customers, including the deferral and amortization of certain related costs. The transaction to transfer TMI-2 to TMI-2 Solutions,
LLC was consummated on December 18, 2020, and as a result, during the fourth quarter of 2020 FirstEnergy recognized an
after-tax gain of approximately $33 million, primarily associated with the write-off of a tax related regulatory liability. Included
within the segment is $45 million of assets classified as held for sale as of December 31, 2020 associated with the asset
purchase agreement with Yards Creek; see Note 12, "Regulatory Matters," for additional information.
The Regulated Transmission segment provides transmission infrastructure owned and operated by the Transmission
Companies and certain of FirstEnergy's utilities (JCP&L, MP, PE and WP) to transmit electricity from generation sources to
distribution facilities. The segment's revenues are primarily derived from forward-looking formula rates. Under forward-looking
formula rates, the revenue requirement is updated annually based on a projected rate base and projected costs, which is subject
to an annual true-up based on actual rate base and costs. The segment's results also reflect the net transmission expenses
108
related to the delivery of electricity on FirstEnergy's transmission facilities. On November 6, 2021, FirstEnergy, along with FET,
entered into the FET P&SA, with Brookfield and Brookfield Guarantors pursuant to which FET agreed to issue and sell to
Brookfield at the closing, and Brookfield agreed to purchase from FET, certain newly issued membership interests of FET, such
that Brookfield will own 19.9% of the issued and outstanding membership interests of FET, for a purchase price of $2.375 billion.
The transaction is subject to customary closing conditions, including approval from the FERC and review by the CFIUS. KATCo,
which is currently a subsidiary of FET, will become a wholly owned subsidiary of FE prior to the closing of the transaction and will
remain in the Regulated Transmission segment.
Corporate/Other reflects corporate support and other costs not charged or attributable to the Utilities or Transmission
Companies, including FE's retained Pension and OPEB assets and liabilities of the FES Debtors, interest expense on FE’s
holding company debt and other businesses that do not constitute an operating segment. Reconciling adjustments for the
elimination of inter-segment transaction are shown separately in the following table of Segment Financial Information. As of
December 31, 2021, 67 MWs of electric generating capacity, representing AE Supply's OVEC capacity entitlement, is included in
Corporate/Other. As of December 31, 2021, Corporate/Other had approximately $7.9 billion of FE holding company debt.
109
Financial information for each of FirstEnergy’s business segments and reconciliations to consolidated amounts is presented in
the tables below. FirstEnergy evaluates segment performance based on Income (loss) from continuing operations.
Segment Financial Information
For the Years Ended
December 31, 2021
External revenues
Internal revenues
Total revenues
Provision for depreciation
Amortization of regulatory assets, net
DPA penalty
Miscellaneous income (expense), net
Interest expense
Income taxes (benefits)
Income (loss) from continuing operations
Property additions
December 31, 2020
External revenues
Internal revenues
Total revenues
Provision for depreciation
Amortization (deferral) of regulatory assets, net
Miscellaneous income (expense), net
Interest expense
Income taxes (benefits)
Income (loss) from continuing operations
Property additions
December 31, 2019
External revenues
Internal revenues
Total revenues
Provision for depreciation
Amortization (deferral) of regulatory assets, net
Miscellaneous income (expense), net
Interest expense
Income taxes
Income (loss) from continuing operations
Property additions
As of December 31, 2021
Total assets
Total goodwill
As of December 31, 2020
Total assets
Total goodwill
Regulated
Distribution
Regulated
Transmission
Corporate/
Other
(In millions)
Reconciling
Adjustments
FirstEnergy
Consolidated
$
$
$
$
$
$
$
$
$
$
9,510 $
201
9,711
911
260
—
399
523
364
1,288
1,395 $
9,168 $
195
9,363
896
(64)
332
501
113
959
1,514 $
9,511 $
187
9,698
863
(89)
174
495
271
1,076
1,473 $
1,608 $
10
1,618
325
9
—
41
248
127
408
958 $
1,613 $
17
1,630
313
11
30
219
138
464
1,067 $
1,510 $
16
1,526
284
10
15
192
113
447
1,090 $
14 $
—
14
3
—
230
89
382
(171)
(457)
92 $
9 $
—
9
4
—
83
358
(125)
(420)
76 $
14 $
—
14
5
—
80
372
(171)
(619)
102 $
— $
(211)
(211)
63
—
—
(12)
(12)
—
—
— $
— $
(212)
(212)
61
—
(13)
(13)
—
—
— $
— $
(203)
(203)
68
—
(26)
(26)
—
—
— $
11,132
—
11,132
1,302
269
230
517
1,141
320
1,239
2,445
10,790
—
10,790
1,274
(53)
432
1,065
126
1,003
2,657
11,035
—
11,035
1,220
(79)
243
1,033
213
904
2,665
30,812 $
5,004 $
13,237 $
614 $
1,383 $
— $
— $
— $
45,432
5,618
30,855 $
5,004 $
12,592 $
614 $
1,017 $
— $
— $
— $
44,464
5,618
110
CONTROLS AND PROCEDURES
Evaluation of Disclosure Controls and Procedures
FirstEnergy has established disclosure controls and procedures to ensure that information is accumulated and communicated to
management, including the chief executive officer and chief financial officer, as appropriate to allow timely decisions regarding
required disclosure, and ensure that information required to be disclosed in the reports FirstEnergy files or submits under the
Exchange Act, is recorded, processed, summarized and reported, within the time periods specified in the SEC’s rules and forms.
The management of FirstEnergy, with the participation of the chief executive officer and chief financial officer, have evaluated the
effectiveness of its disclosure controls and procedures (as defined in Rules 13a-15(e) and 15d-15(e) under the Exchange Act, as
of December 31, 2021. Based on that evaluation, the chief executive officer and chief financial officer of FirstEnergy have
concluded that its disclosure controls and procedures were effective as of December 31, 2021.
Management’s Report on Internal Control over Financial Reporting
Management of the FirstEnergy is responsible for establishing and maintaining adequate internal control over financial reporting
as defined in Rules 13a-15(f) and 15d-15(f) under the Exchange Act. FirstEnergy’s internal control over financial reporting is a
process designed to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial
statements for external purposes in accordance with generally accepted accounting principles. Because of its inherent
limitations, internal control over financial reporting may not prevent or detect misstatements. Also, projections of any evaluation
of effectiveness to future periods are subject to the risk that controls may become inadequate because of changes in conditions,
or that the degree of compliance with the policies or procedures may deteriorate.
Management conducted an evaluation of the effectiveness of FirstEnergy's internal control over financial reporting as of
December 31, 2021, based on the framework in "Internal Control-Integrated Framework" (2013) issued by the Committee of
Sponsoring Organizations of the Treadway Commission (COSO). Based on that evaluation, management concluded that
FirstEnergy's internal control over financial reporting was effective as of December 31, 2021
The effectiveness of FirstEnergy’s internal control over financial reporting as of December 31, 2021 has been audited by
PricewaterhouseCoopers LLP, an independent registered public accounting firm, as stated in their report, which is included
herein.
Remediation of Previous Material Weakness in Internal Control over Financial Reporting
As disclosed in FirstEnergy's Form 10-K for the fiscal year ended December 31, 2020, management previously identified a
material weakness in FirstEnergy's internal control over financial reporting related to its senior management failing to set an
appropriate tone at the top. Management and the FE Board take FirstEnergy’s internal control over financial reporting and the
integrity of its financial statements seriously. FirstEnergy completed the documentation and testing of the remedial actions and
management concluded that as a result of the corrective activities implemented, the previously disclosed material weakness had
been remediated as of September 30, 2021. Management, the FE Board, along with the Audit Committee, and its subcommittee,
remediated the material weakness by focusing on people, training, and communication as detailed in the following remedial
activities:
•
•
•
•
•
•
•
•
the appointment of a new Chief Executive Officer to improve the tone at the top;
the termination of certain members of senior management, including FirstEnergy’s former Chief Executive Officer, for
violations of certain FirstEnergy policies and its code of conduct;
the separation of two senior members of the legal department, due to inaction and conduct that the FE Board
determined was influenced by the improper tone at the top;
the establishment of a subcommittee of FirstEnergy’s Audit Committee, who, with the FE Board, assessed the
compliance program, provided recommendations, and has overseen and will continue to oversee the implementation of
changes (as appropriate) in FirstEnergy’s compliance program;
the appointment of a new Chief Legal Officer;
the appointment of a new Vice Chair of the FE Board and Executive Director to help lead efforts to enhance
FirstEnergy’s reputation with external stakeholders;
the appointment of new independent directors to the FE Board;
the appointment of a new Chief Ethics & Compliance Officer who is overseeing the ethics and compliance program and
implementation of enhancements to the existing compliance structure and role;
111
•
•
the FE Board's reinforcement of and executive team’s recommitment to the importance of setting appropriate tone at the
top and the expectation to demonstrate FirstEnergy’s core values and behaviors which support an ethical and compliant
culture, as well as adherence to internal control over financial reporting; and
increased communication and training of employees with respect to:
•
•
•
•
FirstEnergy’s commitment to ethical standards and integrity of its business procedures,
compliance requirements,
FirstEnergy’s code of conduct and other FirstEnergy policies, and
availability of and the process for reporting suspected violations of law or code of conduct.
Management and the FE Board are committed to maintaining a strong internal control environment and believe the above efforts,
which have been tested and are operating effectively, have remediated the material weakness.
Changes in Internal Control over Financial Reporting
During the quarter ended December 31, 2021, there were no changes in internal control over financial reporting (as defined in
Rules 13a-15(f) and 15d-15(f) under the Exchange Act that have materially affected, or are reasonably likely to materially affect,
FirstEnergy's internal control over financial reporting.
112
Information About Our Executive Officers (as of February 16, 2022)
Name
John W. Somerhalder II
Age
66
Positions Held During Past Five Years
Vice Chair and Executive Director (A)
CenterPoint Energy Inc, Interim President & Chief Executive Officer
Colonial Pipeline Co, Interim President & Chief Executive Officer
S. E. Strah
S. L. Belcher
H. Park
58
53
60
K. Jon Taylor
48
President and Chief Executive Officer (A) (B)
President and Acting Chief Executive Officer (A) (B)
Senior Vice President and Chief Financial Officer (A) (B) (C) (E)
President (D)
President (C) (E)
Senior Vice President & President, FirstEnergy Utilities (B)
Senior Vice President, Operations (B)
President (C) (E)
Senior Vice President and President, FirstEnergy Utilities (B)
President and Chief Nuclear Officer (G)
President, FirstEnergy Nuclear Operating Company (B)
Senior Vice President and Chief Legal Officer (A)
Senior Vice President and General Counsel (C) (D) (E)
LimNexus, Partner and General Counsel
Latham & Watkins, Of Counsel
PG&E Corporation, Senior Vice President and Special Counsel to Chairman
PG&E Corporation, Senior Vice President and General Counsel
Senior Vice President, Chief Financial Officer and Strategy (A) (B)
Senior Vice President and Chief Financial Officer (C) (E)
Senior Vice President and Chief Financial Officer (A) (B)
Vice President, Utility Operations (B)
President (D)
President, Ohio Operations (B)
Vice President (C)
Vice President and Controller (C) (E)
Vice President, Controller and Chief Accounting Officer (A) (B)
Vice President and Controller (D) (G)
J. J. Lisowski
C. L. Walker
40
56
Vice President, Controller and Chief Accounting Officer (A) (B)
Vice President and Controller (C) (E)
Controller and Treasurer (G)
Controller and Treasurer (F)
Assistant Controller (B) (C) (D) (E) (G)
Senior Vice President and Chief Human Resources Officer (B)
Vice President, Human Resources (B)
Executive Director, Talent Management (B)
* Indicates position held at least since January 1, 2017
(A) Denotes position held at FE
(B) Denotes position held at FESC
(C) Denotes position held at the Ohio Companies, the Pennsylvania Companies, MP, PE, FET, KATCo, TrAIL and ATSI
(D) Denotes position held at AGC
(E) Denotes position held at MAIT
(F) Denotes position held at FES and FG
(G) Denotes position held at FENOC
Dates
2021-Present
2020
2017
2021-Present
2020-2021
2018-2020
2017-2018
*-2018
*-2018
2021-Present
2018-Present
2018-2021
*-2018
*-2017
2021-Present
2021-Present
2019-2021
2017-2019
2017
*-2017
2021-Present
2020-Present
2020-2021
2019-2020
2019-2020
2018-2019
2018-2019
*-2018
*-2018
*-2017
2018-Present
2018-Present
2017-2018
*-2018
*-2017
2019-Present
2018-2019
*-2018
113
SHAREHOLDER SERVICES
TRANSFER AGENT AND REGISTRAR
American Stock Transfer & Trust Company, LLC (AST) is the company’s Transfer Agent and Registrar. Registered shareholders wanting to transfer stock,
or who need assistance or information, can send their stock certificate(s) or write to FirstEnergy Corp., c/o American Stock Transfer & Trust Company,
LLC, P.O. Box 2016, New York, NY 10272-2016. Shareholders also can call toll-free at 1-800-736-3402, between 8 a.m. and 8 p.m. Eastern time, Monday
through Friday. For internet access to general shareholder and account information, visit the AST website at www.astfinancial.com.
STOCK INVESTMENT PLAN
Registered shareholders and employees of the company can participate in the FirstEnergy Corp. Stock Investment Plan. To learn more about the
company’s Stock Investment Plan, visit AST’s website at https://us.astfinancial.com/InvestOnline/Invest/AllPlan, or contact AST toll-free at 1-800-736-3402.
DIRECT DIVIDEND DEPOSIT
Registered shareholders can have their dividend payments automatically deposited to checking, savings or credit union accounts at any financial
institution that accepts electronic direct deposits. Using this free service ensures that payments will be available to you on the payment date, eliminating
the possibility of mail delay or lost checks. Contact AST toll-free at 1-800-736-3402 to receive a Direct Dividend Deposit Authorization Agreement.
STOCK LISTING AND TRADING
The common stock of FirstEnergy Corp. is listed on the New York Stock Exchange under the symbol FE.
FORM 10-K ANNUAL REPORT
The Annual Report on Form 10-K, as filed with the Securities and Exchange Commission, including the financial statements and financial statement
schedules, will be sent to you without charge upon written request to Mary M. Swann, Corporate Secretary and Associate General Counsel,
FirstEnergy Corp., 76 South Main Street, Akron, Ohio 44308-1890. You also can view the Form 10-K by visiting the company’s website at
www.firstenergycorp.com/investor.
NON-GAAP FINANCIAL MEASURES
*Operating earnings (loss) per share excludes “special items” as described below, and is a non-GAAP financial measure. Special items represent charges
incurred or benefits realized that management believes are not indicative of, or may obscure trends useful in evaluating the Company’s ongoing core
activities and results of operations or otherwise warrant separate classification. Special items are not necessarily non-recurring. Management uses
Operating earnings (loss) and Operating earnings (loss) per share to evaluate the Company’s performance and manage its operations and frequently
references these non-GAAP financial measures in its decision making, using them to facilitate historical and ongoing performance comparisons. Operating
EPS is calculated by dividing Operating earnings (loss), which excludes special items as discussed above, for the periods presented by 539 million shares
for 2019, which reflects the full impact of share dilution from the equity issuance in January 2018, 542 million shares for 2020 and 545 million shares for
year 2021. Basic (GAAP) EPS is based on 535 million shares for 2019, 542 million shares for 2020 and 545 million shares for 2021.
Management believes that the non-GAAP financial measures of Operating earnings (loss) and Operating earnings (loss) per share provide consistent and
comparable measures of performance of its businesses on an ongoing basis. Management also believes that such measures are useful to shareholders
and other interested parties to understand performance trends and evaluate the Company against its peer group by presenting period-over-period
operating results without the effect of certain charges or benefits that may not be consistent or comparable across periods or across the Company’s peer
group. Generally, a non-GAAP financial measure is a numerical measure of a company’s historical or future financial performance, financial position, or
cash flows that either excludes or includes amounts that are not normally excluded or included in the most directly comparable measure calculated and
presented in accordance with accounting principles generally accepted in the United States (GAAP). These non-GAAP financial measures are intended to
complement, and are not considered as alternatives to, the most directly comparable GAAP financial measures. Also, the non-GAAP financial measures
may not be comparable to similarly titled measures used by other entities. Pursuant to the requirements of Regulation G, FirstEnergy has provided,
where possible without unreasonable effort, quantitative reconciliations within this presentation of the non-GAAP financial measures to the most directly
comparable GAAP financial measures.
Net Income Attributable to Common Stockholders (GAAP) – $M
Basic Earnings per Share (GAAP)
Excluding special items*:
Pension/OPEB mark-to-market adjustments –
Impact of full dilution
Regulatory charges (credits)
Asset impairments
Exit of generation costs (credits)
State tax legislative changes
Investigation and other related costs
FE Forward cost to achieve
Total special items*
Operating Earnings per Share (non-GAAP)
2019
$ 908
$ 1.70
0.89
(0.01)
(0.16)
—
0.16
—
—
—
0.88
$ 2.58
2020
$ 1,079
$ 1.99
0.60
—
0.01
—
(0.21)
—
—
—
0.40
$ 2.39
2021
$ 1,283
$ 2.35
(0.48)
—
0.30
0.01
(0.19)
0.02
0.58
0.01
0.25
$ 2.60
Per share amounts for the special items and earnings drivers above and throughout this report are based on the after-tax effect of each item
divided by the number of shares outstanding for the period. The current and deferred income tax effect, which ranges from 21% to 29% in all
periods, was calculated by applying the subsidiaries’ statutory tax rate to the pre-tax amount if deductible/taxable.
76 South Main Street, Akron, Ohio 44308-1890