RENEWING
OUR
COMMITMENT
> 2019 INTEG R ATED A N N UA L R EPOR T
M E S S A G E F R O M O U R C E O :
THE
ENERGY
WORLD IS
CHANGING
RAPIDLY.
DURING 2019 WE
CONTINUED TO ADAPT,
DRIVEN BY OUR GOAL
OF RANKING AMONG
THE COUNTRY’S
PREMIER REGULATED
GAS AND ELECTRIC
COMPANIES.
SAFET Y IS FOUNDATIONAL
In all our efforts, safety leadership remains
our foundational commitment. We are
advancing that commitment with accelerated
implementation of a Safety Management
System, or SMS, across our company.
Through SMS – aligned with a framework
developed for pipeline operators by the
American Petroleum Institute – we are
increasing our rigor in identifying risks
and taking action to keep our customers,
communities, employees and contractors safe.
REBUILDING TRUST
We reached a milestone last fall when
the National Transportation Safety Board
(NTSB) issued its final report on the
September 2018 event in the Merrimack
Valley of Massachusetts, and accepted our
responses to its last two remaining urgent
safety recommendations (the other two
were accepted in July 2019). And we’ve
made substantial progress on enhancing
our emergency preparedness and response
capabilities, which was the subject of a
September 2019 NTSB recommendation.
While safety is our No. 1 priority, we’re
also working to regain the trust of all our
stakeholders following that tragic event.
Reflecting this commitment, we have
completed our restoration efforts in Andover,
Lawrence and North Andover, Massachusetts,
including replacing all affected customer
equipment and restoring outdoor areas
disturbed by our 2018 construction work.
Further, a dedicated team remains in place
to provide continued support to affected
customers. And we have made safety
enhancements to low-pressure gas systems
across our seven states.
We also announced in February 2020 that
we have agreed to sell Columbia Gas of
Massachusetts (CMA) to Eversource Energy,
SERVING NEARLY
4 MILLION
NATURAL GAS AND ELECTRIC CUSTOMERS
ACROSS SEVEN STATES UNDER OUR
COLUMBIA GAS AND NIPSCO BRANDS.
A NiSource Company
New England’s largest energy delivery company.
We believe this transaction will create the right
next chapter for the customers and communities
that CMA serves throughout the state, as well
as its dedicated employees. (For additional
information, please see the article on page 16.)
TR ANSFORMING OUR
ELECTRIC BUSINESS
We made significant progress in 2019 on
transforming our electric business. We have
three wind projects in progress in Indiana
and are actively seeking additional renewable
resources to replace our coal-fired generating
capacity, all of which is scheduled to be retired
by 2028. From a base year of 2005, these
initiatives are expected to drive a 90 percent
reduction in NiSource’s greenhouse gas
emissions by 2030, and to save customers
more than $4 billion over 30 years.
We also continued to execute on our seven-
year electric infrastructure modernization
program that we began in 2016. This included
enhancements to our electric transmission and
distribution system designed to further improve
system safety and reliability. These strategies
were supported by the successful conclusion
of our electric base rate case, which also
contained elements that reduce our risk profile.
SUPPORTING SUSTAINABILIT Y
In September 2019, NiSource was named
to the Dow Jones Sustainability North America
Index for the sixth consecutive year. We are
one of three U.S. multi-utility companies on the
list, which acknowledges advancements we
continue to make in our sustainability strategy.
This includes aggressive greenhouse gas
reduction targets and executing against more
than $30 billion of long-term infrastructure
and safety investments over 20 years. We are
committed to delivering energy safely, reliably
and in an environmentally responsible and
sustainable way.
LONG -TERM GROW TH
FOR INVESTORS
NiSource results in 2019 met our financial
commitments to investors. We delivered
full-year non-GAAP net operating earnings
per share of $1.32*, near the top of our
guidance range for the year. We made
$1.9 billion in capital infrastructure and
safety investments in our gas and electric
systems, while maintaining our current
investment-grade credit ratings and
executing on our regulatory plan.
Due to the expected closing of the CMA
transaction later this year, we have
withdrawn our 2020 net operating earnings
per share (non-GAAP) guidance of $1.36
to $1.40. However, we still expect to make
capital investments of $1.8 to $1.9 billion
this year, and we expect we will no longer
need a block equity issuance in 2020.
The long-term growth opportunity for
our remaining operating companies
is unchanged. As a result, following
completion of the CMA transaction,
we expect to initiate 2021 net operating
earnings per share guidance and
establish a 5 to 7 percent long-term
growth rate for both net operating earnings
per share (non-GAAP) and our dividend,
with 2021 as the base year. This new long-
term guidance is expected to be extended
beyond 2022 to include significant
investments related to our electric
generation strategy.
CONTINUOUS LEARNING
AND IMPROVEMENT
MINDSET
We are committed to continually improving
the safety, reliability and environmental
performance of our systems, service
quality for customers and our employee
experience, all with a goal of delivering
increasing value for all of our stakeholders.
I want to thank our Board of Directors,
management team and the entire
NiSource team for their dedication
and hard work that contributed to the
company’s success in 2019, and look
forward to working together energetically
to further deliver on our commitments in
*Net operating earnings per share
(non-GAAP); for a reconciliation to
GAAP, see Schedule 1 on page 26.
See also Regulation G statement on
the inside back cover.
JOE HAMROCK
President and CEO
NiSource Inc.
March 13, 2020
BOARD OF
DIRECTORS
Kevin T. Kabat
Chairman of the Board, NiSource, Retired
Vice Chairman and CEO, Fifth Third Bancorp
SENIOR
MANAGEMENT
TEAM
Joseph Hamrock
President and Chief Executive Officer
Peter A. Altabef
Chairman and CEO, Unisys Corporation
Donald E. Brown
Executive Vice President and Chief Financial Officer
Theodore H. Bunting, Jr.
Retired Group Vice President, Utility
Operations, Entergy Corporation
Eric L. Butler
President and CEO, Aswani-Butler Investment
Associates and Retired Executive Vice
President, Union Pacific Corporation
Aristides S. Candris
Retired President and CEO,
Westinghouse Electric Company
Wayne S. DeVeydt
Executive Chairman of the Board,
Surgery Partners, Inc.
Joseph Hamrock
President and CEO, NiSource Inc.
Deborah A. Henretta
Partner, G100 Companies and Retired Group
Vice President, Procter & Gamble Co.
Deborah A. P. Hersman
Chief Safety Officer, Waymo LLC
and Former Chair, National Transportation
Safety Board (NTSB)
Michael E. Jesanis
Managing Director, HotZero LLC and Retired
President and CEO, National Grid USA
Carrie J. Hightman
Executive Vice President and Chief Legal Officer
Violet G. Sistovaris
Executive Vice President and President, NIPSCO
Pablo A. Vegas
Executive Vice President and President, Gas Utilities
Chuck Shafer
Senior Vice President and Chief Safety Officer
Suzanne K. Surface
Chief Services Officer
Ken Keener
Senior Vice President and Chief Human Resources Officer
Peter T. Disser
Vice President, Internal Audit
SENIOR MANAGEMENT TEAM
WORKFORCE STATS (As of March 1, 2020)
9 Total
67% Men, 33% Women, 22% Minorities
QUALITY REVIEW BOARD
Carolyn Y. Woo
Retired President and CEO, Catholic Relief
Services
Ray LaHood
Quality Review Board Chair
Former Secretary, U.S. Dept. of Transportation
BOARD OF DIRECTORS
WORKFORCE STATS
(As of March 1, 2020)
11 Total
73% Men, 27% Women, 27% Minorities
John Durham
Retired Director, ENERCON Services
Gary Harland
President, Work Management Inc.
Cynthia Quarterman
Former Administrator, Pipeline and Hazardous
Materials Safety Administration
John Cox
President and CEO, Safety Operating Systems
Jeff Wiese
Vice President, TRC Companies
C H A I R M A N ’ S L E T T E R :
REFLECTING
on my first year as Chairman of the NiSource Board of Directors, it has been a year of sharp
focus on the continuing recovery from the tragic September 2018 event in the Merrimack Valley
of Massachusetts. We worked diligently to rebuild the three impacted communities and support
our customers in the valley and beyond. In addition, we executed a robust capital investment
program while maintaining a focus on the things that matter most to all of our stakeholders –
safety, service reliability, sustainability and long-term value for our shareholders.
We have a highly skilled Board of Directors and senior management team armed with the
knowledge and diversity of business experience needed to make sound strategic decisions
on behalf of all our constituents. It has been a privilege to work with them in overcoming
challenges and driving toward our goal of being a premier regulated gas and electric company.
Our most critical priority in 2019 was to advance our culture of
safety to protect our customers, communities, employees and
contractors – and this will endure as our top priority. Central
to that is our accelerated Safety Management System (SMS)
implementation, which has led to enhanced risk management
processes for our gas and electric operations.
We also were pleased to welcome Deborah Hersman to the Board. She is an experienced
safety executive, having served as Chair of the National Transportation Safety Board and CEO
of the National Safety Council. Her perspective is invaluable as we continue to improve our
safety performance.
Our core commitment to safety is an important element of our comprehensive focus on
sustainability. We are transitioning from coal-fired to renewable generation in our electric
business, and we are fully committed to investments in our gas business that are designed to
drive safe, reliable, modern service with better environmental performance.
We also commend our employees in their commitment to serving customers and enhancing
stakeholders’ experiences with our companies. Their dedication extends into our communities,
where they give hours of their time to volunteerism. This is a hands-
on element of NiSource’s focus on social responsibility, which includes
charitable contributions of nearly $4.9 million made to education and other
community initiatives in 2019.
The Board of Directors is committed to working closely with – and
continuing to challenge – Joe and the senior management team as we
work together toward achieving our common goals for our stakeholders
and enhancing value for our shareholders.
KEVIN KABAT
Chairman of the Board | NiSource Inc. | March 13, 2020
RENEWING
OUR
COMMITMENT
During 2019, across NiSource, we recommitted ourselves to delivering
value for our customers, communities, investors and business partners as
well as improving the employee experience. On behalf of all stakeholders,
we strengthened our safety culture, continued to modernize our energy
delivery infrastructure, made significant strides in transforming our electric
business, and continued to contribute to the communities where we live
and work. This renewal of our core commitments positions us well for
further sustainable growth and success going forward.
WHAT’S
INSIDE
CHAMPIONING SAFETY
TRANSFORMING OUR ELECTRIC BUSINESS
PRESERVING OUR ENVIRONMENT
CREATING THE NEXT CHAPTER FOR CMA
SERVING OUR CUSTOMERS AND COMMUNITIES
EMPOWERING OUR TEAM
FOCUSING ON OUR FINANCIAL PERFORMANCE
6
10
12
16
18
20
24
CHAMPIONING
SAFETY
In 2019, we enhanced the rigor of our safety commitment
through a significant investment of time and resources
in accelerating implementation of a Safety Management
System (SMS). SMS is a comprehensive approach to
managing safety that has been a decisive factor in reducing
incidents in the aviation and nuclear power industries.
It emphasizes continual assessment and improvement
and mitigating potential risks before they happen.
█ 6
C H A M P I O N I N G S A F E T Y
Our SMS vision is to lead and exceed the
industry in safety. In our culture, everyone
is empowered to identify and report risk,
which is the foundation for enhancing
process safety with layers of protection
and building accountability for effective
asset management to reduce risk.
In 2019, we made substantial progress in shifting SMS from
a project to full organizational ownership, realigning our teams
to better protect our employees, contractors, customers and
communities. Major safety accomplishments include:
ADDING
safety expert and former chair of the
National Transportation Safety Board (NTSB)
Deborah Hersman to our Board of Directors.
CREATING
a new Chief Safety Officer position,
filled by NiSource executive Chuck Shafer,
reporting directly to CEO Joe Hamrock.
IMPLEMENTING
the National Transportation Safety
Board’s urgent safety recommendations
following the September 2018 event
in Massachusetts.
TRAINING
nearly 90 percent of our Gas Segment
employees on SMS in 2019; the
remainder will be trained this year.
INTEGRATING
safety, compliance and risk management
functions at each NiSource operating company
and at the corporate level and increasing
related staffing and capabilities.
DEFINING
asset classes and an integrated planning
process structure, including documenting
SMS standards, polices and processes.
ESTABLISHING
a Corrective Action Program (CAP) tool and
process for employees to use to report risks.
In 2019, 1,536 CAPs were initiated, of which
450 were processed and closed.
EMPOWERING
our people to own safety and stop
work whenever they see an employee,
business partner or member of the
public who is at risk of harm.
█ 7
While we made great progress in 2019, we have more to do to improve safety. We did not
hit our milestones in several key areas related to employee safety. We continue to focus on
building a culture of safety – identifying specific corrective actions we can take to work safer.
Protecting our employees, contractors, customers and communities is – and will remain – our
top priority, the compass that guides all our actions and decisions. Nothing is more important.
CORRECTIVE ACTION PROGR AM (CAP) AT WORK
Our Corrective Action Program (CAP) gives employees a voice to report issues, risks or
concerns they observe. Kentucky Plant/Service Combo Tech Jamie Ensminger submitted a
CAP to recommend the use of pipeline markers as a safer, more permanent solution to mark
difficult-to-locate gas lines at intersections and heavy traffic areas. Jamie saw the
asphalt markers used in Merrimack Valley and thought they could be used to
help reduce the risks associated with locating gas lines in high risk areas.
About the size of poker chips, the devices are implanted flush to the ground
and can be driven and walked over. They permanently mark a line and,
once in place, a GPS tech can record the location of the devices. Even
if the markers are covered with snow, dirt or blacktop, technicians can
use GPS information to find the gas line. A pilot program to test durability
and cost-effectiveness of the pipeline markers in Kentucky is underway.
Thanks, Jamie!
QUALIT Y REVIEW
BOARD (QRB)
We appointed a Quality Review Board,
a group of six independent experts who
evaluate and provide recommendations
for the development, implementation
and overall management of SMS based
on their experiences and lessons
learned across diverse backgrounds
spanning the nuclear, aviation and
energy industries. They meet regularly to
validate the rigor, quality, thoroughness
and completeness of our SMS work.
Through its implementation of SMS,
establishment of an independent Quality
Review Board to oversee that work, as
well as the other safety enhancements
and culture-driving changes it has made,
NiSource is clearly an industry leader.
Ray LaHood
Chairman, NiSource Quality Review Board, former
U.S. Congressman and U.S. Secretary of Transportation
█ 8
C H A M P I O N I N G S A F E T Y
SAFETY AND INFRASTRUCTURE
INVESTMENTS BY THE NUMBERS
$30
BILLION
IN IDENTIFIED LONG-
TERM INVESTMENTS
~$1.9
BILLION
INVESTED IN GAS AND ELECTRIC
SAFETY AND INFRASTRUCTURE
MODERNIZATION PROGRAMS IN 2019
337
MILES
OF PRIORITY PIPE
REPLACED IN 2019
33
MILES
OF UNDERGROUND ELECTRIC
CABLE REPLACED IN 2019
1,959
ELECTRIC POLES
REPLACED IN 2019
>1,000
LOW PRESSURE GAS SYSTEM SAFETY
ENHANCEMENTS, INCLUDING THE
INSTALLATION OF AUTOMATIC
SHUT-OFF DEVICES TO PROTECT
AGAINST OVERPRESSURIZATION
█ 9
TRANSFORMING
OUR ELECTRIC BUSINESS
Our plans call for retiring all of our remaining coal-fired
electric generation by 2028, and we plan to have nearly
80 percent retired by 2023. This capacity will be replaced
with lower-cost, reliable and cleaner options. As a result,
the plan would save Northern Indiana Public Service
Company (NIPSCO) electric customers more than $4 billion
over 30 years and is expected to drive a 90 percent
reduction in our greenhouse gas emissions by 2030,
from a base year of 2005.
█ 10
T R A N S F O R M I N G O U R E L E C T R I C B U S I N E S S
One key to achieving this goal for our
electric business is the addition of wind
power to our generation portfolio. During
2019, we reached commercial agreements
on multiple wind projects in Indiana.
NIPSCO was one of the nation’s top three wind power purchasers (AT&T and Walmart were the
others) in 2019, according to the American Wind Energy Association, which reported that utilities
represented 60 percent of wind power purchase activity in 2019. In December 2019, the Federal
Energy Regulatory Commission (FERC) approved NIPSCO’s Section 203 and 205 applications for
Rosewater, one of three wind projects announced early in the year. The Indiana Utility Regulatory
Commission (IURC) had previously approved the joint venture and ownership agreement for
Rosewater, as well as applications for two other projects – Jordan Creek and Roaming Bison.
While Roaming Bison has since been cancelled due to local zoning restrictions, construction is
underway on both Rosewater and Jordan Creek, which are expected to be in service by the end
of 2020. The IURC in early 2020 also approved NIPSCO’s application for a fourth wind project,
Indiana Crossroads, a joint venture with EDP Renewables North America. Indiana Crossroads
is expected to be in operation by the end of 2021.
Our Indiana electric team is also working to identify additional
resources to replace our retiring coal generation capacity.
It completed a Request for Proposals process in November
2019 and has begun discussions with a number of commercial
bidders who responded. In addition, NIPSCO continues to execute
on its seven-year electric infrastructure modernization program
that we put in place in 2016. This includes:
$1.2
BILLION
OF ENHANCEMENTS TO THE
ELECTRIC TRANSMISSION AND
DISTRIBUTION SYSTEM IN 2019
DESIGNED TO FURTHER IMPROVE
SYSTEM SAFETY AND RELIABILITY.
On the state regulatory front, NIPSCO secured IURC approval in
December 2019 of its electric base rate case, with new rates effective
in January 2020. The outcome of the case supported our electric
generation strategy, with new depreciation schedules related to the
early retirement of our coal-fired generation. The IURC order also
established a return on equity of 9.75 percent, reflecting a reduced
business risk profile and a new more flexible service and rate
structure for our industrial customers.
█ 11
PRESERVING OUR
ENVIRONMENT
In everything we do, we consider the economic, social and
environmental impact of our operations. We’re making significant
investments to ensure that we can continue to deliver energy to
our customers where and when they need it, and in a way that
is affordable and environmentally responsible.
ENVIRONMENTAL IMPACT TARGETS
2025
REDUCTIONS
FROM 2005
LEVELS
2030
REDUCTIONS
FROM 2005
LEVELS
NITROGEN OXIDES,
SULFUR DIOXIDE
AND MERCURY
WATER
WITHDRAWAL
WASTEWATER
DISCHARGE
COAL ASH
GENERATED
90%
90%
60%
50%
99% ON TRACK
99% ON TRACK
99% ON TRACK
100% ON TRACK
GREENHOUSE GAS
(ELECTRIC GENERATION) 50%
90%+ ON TRACK
METHANE (PIPELINE
REPLACEMENT)
50%
50%+ ON TRACK
GREENHOUSE
GAS
REDUCTIONS
FROM 2005
LEVELS
50%BY 2025
90%BY 2030
█ 12
P R E S E R V I N G O U R E N V I R O N M E N T
TRANSITIONING TO LOWER-COST,
RENEWABLE ENERGY SOURCES
We are taking steps to ensure a cleaner, more sustainable energy future.
Our plans to retire all of our coal-fired electric generation by 2028 and replace that capacity
with lower-cost, cleaner energy sources is projected to result, by 2030 ‒ compared with a base
year of 2005 ‒ in a 90 percent reduction of greenhouse gas emissions, a 100 percent reduction
of coal ash generated and a 99 percent reduction of water withdrawal, wastewater discharge,
and nitrogen oxides, sulfur dioxide, and mercury air emissions. It also is projected to result
in more than $4 billion in long-term cost savings for customers over 30 years.
90%
REDUCTION
OF GREENHOUSE GAS EMISSIONS
100%
REDUCTION
OF COAL ASH GENERATED
99%
REDUCTION
OF WATER WITHDRAWAL,
WASTEWATER DISCHARGE, AND
NITROGEN OXIDES, SULFUR DIOXIDE,
AND MERCURY AIR EMISSIONS
$4
BILLION
IN LONG-TERM COST
SAVINGS FOR CUSTOMERS
█ 13
REDUCING
EMISSIONS IN OUR GAS
DISTRIBUTION OPERATIONS
Through our modernization programs and the five-year effort we initiated in 2016 through
U.S. EPA’s Natural Gas STAR Methane Challenge Program, our companies collectively
have reduced pipeline methane emissions by 37 percent compared with 2005 levels. Further,
we remain on track to reach our 50 percent methane reduction target by 2025. We also
want to help customers reduce their carbon emissions through participation in our programs
for energy-efficiency upgrades, home check-ups and weatherization services. In 2019:
NEARLY
$21
MILLION
SAVINGS WERE ACHIEVED
ON THEIR ENERGY BILLS
MORE THAN
ONE
MILLION
CUSTOMERS
PARTICIPATED
█ 14
P R E S E R V I N G O U R E N V I R O N M E N T
CONTINUING TO HELP
OUR POLLINATORS
We are committed to transforming our
pipeline rights-of-way into pollinator
habitats. This effort was recognized
in 2019 by the Wildlife Habitat Council
(WHC). It awarded Columbia Gas of
Ohio’s right-of-way program the WHC
Conservation Certification as Certified
Silver – which acknowledges the
company’s leadership among more than
700 WHC Conservation Certification
programs. Right-of-way sites in Ohio
were identified and converted into
pollinator habitats through the planting
of native grasses and pollinator plants,
such as common milkweed, coneflower
and butterfly milkweed, which attract
butterflies and bees. Right-of-way
programs also were launched in
Kentucky and Pennsylvania.
SUSTAINABILIT Y REPORTS
In August 2019 we published our 2018 Climate Report, a detailed description of progress
toward achieving our targets for greenhouse gas emissions reduction. In the report,
we also commit to delivering the most cost-effective, balanced and reliable energy to
our customers and to supporting local economies in the communities we serve. The
report incorporates recommendations from the Task Force on Climate-Related Financial
Disclosures (TCFD) to disclose governance, strategy, risk management and metrics
around climate-related risks and opportunities.
In addition to our Climate Report, we collaborated with the American Gas Association
(AGA) and the Edison Electric Institute (EEI) on development of their joint environmental,
social, governance (ESG) and sustainability reporting template. It provides investors with
both quantitative and qualitative information on a uniform basis. We plan to utilize this
template for our 2019 ESG and sustainability reporting later this year.
Our latest ESG and sustainability documents, including
our 2018 Climate Report, are available on our website at
Nisource.com/company/sustainability/reports-and-policies
█ 15
CREATING
THE NEXT
CHAPTER
FOR COLUMBIA GAS
OF MASSACHUSETTS
Since the September 2018 event in the Merrimack Valley of
Massachusetts, we have cooperated fully with the National
Transportation Safety Board in addressing its recommendations
and have dedicated approximately $1 billion towards serving the
needs of local customers, residents and communities.
As a further development, we announced on February 26, 2020,
that we reached a plea agreement with the U.S. Attorney for
the District of Massachusetts intended to resolve the criminal
investigation into the September 2018 event. We agreed to
pay a $53 million fine and to pursue a sale of Columbia Gas
of Massachusetts (CMA). Later that day, we announced an
agreement to sell CMA’s assets to Eversource Energy, New
England’s largest energy delivery company, for $1.1 billion in
cash, subject to closing conditions.
█ 16
C R E AT I N G T H E N E X T C H A P T E R F O R C M A
This followed a thorough evaluation by our Board and management team, who believe
the sale of CMA to Eversource is in the best interests of all of our stakeholders, including
shareholders, customers, employees and the local communities. It will provide Columbia
Gas employees an opportunity to join a strong organization with deep roots in the region
and a commitment to investing to further enhance safety, pipeline integrity and reliability.
Until the transaction closes, which is expected to occur by end of the third quarter of 2020,
we will continue to focus on driving customer safety and service at CMA and making further
enhancements to all areas of operations. In addition, through 2019, we have:
SETTLED
all major civil claims regarding
damages from the event.
PROVIDED
more than $10 million to Merrimack
Valley customers in energy
efficiency incentives and services.
RE-SEEDED
more than 3,500 properties and
completed approximately 300 repairs
to shrubs, walkways and landscaping.
RE-PAVED
four Massachusetts state roads, more
than 150 driveways, private roads
and commercial lots, and poured
approximately 870 concrete projects.
COMPLETED
verification that approximately 5,000
former gas service lines abandoned
as part of the recovery effort are
now compliant with federal, state and
Columbia Gas requirements.
DONATED
more than $20 million to local
communities and charities.
MAINTAINED
operation of the Lawrence
Customer Care Center, which
will remain open through
September 2020 to continue
serving customers.
What happened in 2018 was tragic,
and we have taken responsibility for
it as well as significant restoration
and safety steps since then. The
expected sale will allow CMA to be
part of a strong local gas distribution
network at Eversource dedicated
to system reliability and safety –
further fulfilling our commitment to
residents and businesses.
█ 17
SERVING OUR CUSTOMERS AND
COMMUNITIES
OUR GOAL IS TO
CONTINUOUSLY IMPROVE
the levels of service we provide our customers, meeting their
evolving needs safely and reliably across our seven-state
footprint. This is an ongoing process that we take very seriously.
█ 18
S E R V I N G O U R C U S T O M E R S A N D C O M M U N I T I E S
Our customer satisfaction survey results (CSAT)
held steady from 2018 to 2019, although our state
operating companies are showing continuous
improvement overall in year-over-year scores
from consumer studies conducted by J.D. Power
& Associates. Spurred by customer feedback
across multiple channels, we are committed to
attaining top-tier customer satisfaction scores.
as a payment method, which makes paying
energy bills as easy as paying other day-to-day
expenses. Customers also can choose to receive
emergency alerts via phone call, text message or
email. During the year, we worked with our state
operating companies to sharpen our vision for
delivering safety, service and comfort, driving
an even clearer focus on our customers.
ENHANCING CUSTOMERS’
EXPERIENCE
During 2019, we focused on making foundational
upgrades to our customers’ experience. For
example, we launched new customer-facing
websites for Columbia Gas and NIPSCO that
are easy to navigate and that adjust to all devices
and browsers. Making it more convenient for
customers to engage with us has enhanced their
levels of satisfaction.
A primary use of these high-touch channels is
for paying bills. Customers in five of the seven
states in which we operate can now use PayPal
WELCOMING NEW
CUSTOMERS AND
THOSE MOVING
We also conducted a pilot program in Ohio
for new residential customers and those who
were moving. The program was designed to help
them set up their online accounts as well as to
receive safety and energy efficiency information.
This “Welcome Series” will be expanded to
all states in 2020 due to the pilot’s success.
ENRICHING OUR COMMUNITIES IN 2019
14,450
$289,000
HOURS SPENT
volunteering at local
nonprofits that support
education, health and
human services and family
welfare initiatives.
CONTRIBUTED
to organizations through the
NiSource Charitable Foundation
Dollars for Doers program,
which matches each employee’s
volunteerism with a financial
contribution from the foundation.
$4.9
MILLION
was contributed to
organizations in communities
throughout our operating
area, with about $1.5 million
coming from the NiSource
Charitable Foundation.
█ 19
EMPOWERING
OUR
TEAM
EMPLOYEES ARE
THE LIFEBLOOD OF
ANY ORGANIZATION,
and we are dedicated to offering educational
and developmental opportunities that enable our
employees to progress and reach their full potential.
█ 20
E M P O W E R I N G O U R T E A M
We have been focused for several years on diversifying our leadership ranks at the manager level
and above. And we have made progress in this area, with 2019 female representation at these levels
increasing four percentage points compared to 2017, and minority representation increasing three
percentage points over the same period. Our aspiration is to have a workforce that matches the
qualified talent available in the communities we serve. We recognize that we have a gap between
female and minority representation and available talent at the manager level and above. We continue
to be intentional about closing those gaps through both our talent acquisition and internal leadership
development efforts, which are summarized below.
LEADERSHIP
DEVELOPMENT
AND TR AINING
NISOURCE
MENTORING
PROGR AM
Through learning experiences
in the classroom and online,
as well as direct mentoring
and coaching, this initiative is
designed to support all current
and future NiSource leaders
in their efforts to improve their
leadership capabilities.
In 2019, more than 6,000 field
and office-based employees
of all levels participated in a
leadership-based learning or
development program.
To expand our roster of
traditionally underrepresented
leaders, this initiative focuses
on developing and retaining
high-potential employees of
diverse backgrounds.
Nineteen leaders participated
in the NiSource Mentoring
Program in 2019, benefitting
from networking opportunities
and mentoring from our
senior leaders.
TARGETED
DEVELOPMENT FOR
DIVERSE TALENT
PROGR AM
This program supports the career
development of high-performing
individual contributors, supervisors
or managers who are either
female or ethnically diverse.
Participants are matched with
NiSource leaders, acting as career
guides, to receive enhanced
coaching and support designed to
help them create and work through
their career development plans.
Nearly 30 employees participated
in the Targeted Development for
Diverse Talent program in 2019.
SUPPORTING EMPLOYEES THROUGH TR ANSITIONS
A critical part of our electric generation strategy is planning for a thoughtful transition for our
employees. We have a cross-functional team studying future workforce demand across NiSource
to determine where we are able to transition impacted generation employees to new roles, and
focus on retraining and retooling as needed. We are actively exploring partnerships both internally
and externally to design transitions that minimize the disruption to our workforce and customers.
█ 21
IMPORTANCE OF DIVERSIT Y AND INCLUSION
Our employees are passionate
about inclusion and diversity.
One of the ways they can get
involved and make a difference
is by participating in Employee
Resource Groups (ERGs)
and Inclusion and Diversity
(I&D) Councils. Open to all
employees, these councils:
Recruit, retain and accelerate the
development of employees.
Participate in community service efforts
that impact our customers and communities.
Serve as a collaborative voice around
shared issues and concerns.
Broaden understanding and awareness of
inclusion, diversity and cultural competence.
DIVERSIT Y IN ACTION
Sydnee Crews, a NiSource leader in customer care and energy assistance, first found herself
captivated with volunteerism during a stint in Malawi, where her team taught English to locals,
provided basic medical care and helped with construction projects. Over time, Sydnee’s
volunteerism has continued, and she is now focused on people who are often overlooked,
particularly black women and the LGBTQ community. Sydnee brings her passion and love for people
to NiSource, through volunteering and through the employee resource group she helped
found: NiPRIDE. NiPRIDE exists to recruit, retain, develop and support LGBTQ
employees and allies by fostering a safe and inclusive environment while
furthering the spirit of diversity and inclusion. The group meets weekly, and
representatives from throughout NiSource marched in 2019 Pride parades.
In terms of LGBTQ inclusion, NiSource is doing a
good job of starting a conversation. When we started
NiPRIDE, we weren’t sure how it would be received,
but it’s been great. The more diversity of thought we have as a
company, the better equipped we’ll be to serve our customers.
Sydnee Crews
NiSource leader in customer care and energy assistance
█ 22
E M P O W E R I N G O U R T E A M
EMPLOYEE POPULATION
A S O F D E C E M B E R 3 1 , 2 0 1 9
8,363
TOTAL
EMPLOYEES
776
TOTAL
MANAGEMENT
(MANAGER AND ABOVE)
GENERATIONS
<1% T R A DITI O N A LISTS
(1925-1948)
72% M EN
28% WO M EN
15% M I N O RIT Y
67% M EN
33% WO M EN
14% M I N O RIT Y
24% BA BY BO O M ERS
(1949-1964)
27% G EN ER ATI O N X
(1965-1976)
49% M I LLEN NI A LS /
G EN ER ATI O N Y
(1977-PRESENT)
VOLUNTEERISM
REACHES NEW HEIGHTS
Volunteering and a focus on inclusion and
diversity come from the same root – a
compassionate heart. NiSource employees
are active in our communities throughout the
year, but June 2019 marked our first ever
Volunteer Blitz. This is a month to come
together as a company in support of the
important services provided by local non-
profit organizations. Employees submit their
volunteer hours to the NiSource Charitable
Foundation Dollars for Doers program,
which recognizes employee volunteerism
by donating $20 per hour for volunteer
time, up to 25 hours per person per year.
SIGNIFICANT
RECOGNITION IN 2019
Dow Jones Sustainability Index
Recognizes our sustainable business practices
and performance (6th consecutive year).
Bloomberg Gender-Equality Index
Recognizes our efforts to create a work
environment that supports gender equality.
Forbes’ America’s Best Large Employers
Recognizes companies liked best by their
employees (4th consecutive year).
FTSE4Good Index
Recognizes the performance of companies
demonstrating strong Environmental,
Social and Governance (ESG) practices.
█ 23
\
█ 24
FOCUSING
ON OUR FINANCIAL
PERFORMANCE
Our team’s performance in 2019 demonstrated the resiliency of
the NiSource business plan. Our employees remained relentlessly
focused on safety and customer satisfaction. This included
accelerating implementation of our Safety Management System
(SMS), advancing our electric generation strategy in Indiana and
making nearly $1.9 billion of capital investments centered on
infrastructure and safety in our gas and electric systems.
We also delivered 2019 non-GAAP net operating earnings of
about $495 million, or $1.32* per share – near the top of our
2019 guidance range – compared with net operating earnings
of $463 million, or $1.30* per share, in 2018. These results were
accomplished while maintaining our current investment-grade
credit ratings and executing on our regulatory plan.
The biggest drivers of our financial performance were higher
net revenues due to the impact of our long-term infrastructure
modernization investments, which were offset by increased safety-
related spending and higher financing costs due largely to the
September 2018 event in the Merrimack Valley of Massachusetts.
*Net operating earnings per share (non-GAAP); for a reconciliation to GAAP, see Schedule 1 on page 26.
See also Regulation G statement on the inside back cover.
\
F O C U S I N G O N O U R F I N A N C I A L P E R F O R M A N C E
Due to the expected sale of Columbia Gas of Massachusetts (CMA) to Eversource Energy,
which we announced in February 2020 (see article, pages 16-17), we have withdrawn our 2020
net operating earnings per share (NOEPS) non-GAAP guidance of $1.36 to $1.40. However, we
still expect to make capital investments of $1.8 to $1.9 billion in 2020. We also expect the CMA
transaction will enable us to eliminate our previously planned 2020 block equity issuance.
Once the CMA sale is completed, which we anticipate happening by the end of the third quarter,
we expect to initiate 2021 net operating earnings per share guidance and establish a 5 to 7
percent long-term growth rate for both NOEPS and our dividend, with 2021 as the base year.
This new long-term guidance is expected to be extended beyond 2022 to include significant
investments related to our electric generation strategy.
As we work through the impact of the sale – by factoring in the elimination of the block equity
dilution, the loss of CMA earnings and the expected dis-synergies in our remaining business –
we believe that, at a minimum, the 2021 baseline will be at or above our withdrawn 2020 guidance.
FINANCIAL
METRICS
$1.32
2019 NON - GA AP
NET OPER ATING
E ARNINGS PER
SHARE*
$0.88
2019 GA AP
E ARNINGS
PER SHARE
$0.80
2019 PER SHARE
ANNUAL DI V I DEND
(COMMON STOCK )
12.9%
2019 TOTAL
SHAREHOLDER
RETURN
$0.84
2020 PER SHARE
ANNUAL DI V I DEND
PRO JECTED
(COMMON STOCK )* *
BILLI ON TO
$1.8
$1.9
BILLI ON
2020 CAPE X
PRO JECTED
*Net operating earnings per share (non-GAAP); for a reconciliation to GAAP, see Schedule 1 on page 26.
See also Regulation G statement on the inside back cover.
**Dividends are subject to Board approval.
█ 25
SCHEDULE 1 – Reconciliation of Consolidated Net Income (Loss) Available to Common Shareholders
to Net Operating Earnings (Loss) Available to Common Shareholders (Non-GAAP) (unaudited)
(in millions, except per share amounts)
2019
2018
2019
2018
GAAP Net Income (Loss) Available to Common Shareholders
$
(153.0)
$
(19.8)
$
328.0
$
(65.6)
Three Months Ended
December 31,
Twelve Months
Ended December 31,
Adjustments to Operating Income (Loss):
Operating Revenues:
Weather – compared to normal
Greater Lawrence Incident(1)
Operating Expenses:
Plant retirement costs(2)
Greater Lawrence Incident(3)
Franchise rights impairment(4)
Goodwill impairment(5)
Loss on sale of fixed assets and impairments, net
Total adjustments to operating income (loss)
Other Income (Deductions):
Greater Lawrence Incident – charitable contribution(3)
Interest rate swap settlement gain
Loss on early extinguishment of long-term debt
Income Taxes:
Tax effect of above items(6)
Income taxes – discrete items(7)
Total adjustments to net income (loss)
209.7
204.8
0.1
348.6
—
—
—
(90.5)
64.5
322.6
(11.8 )
(10.6 )
(24.8 )
—
—
3.9
—
—
—
(54.2 )
379.0
(233.6 )
(32.5 )
3.9
3.3
830.6
—
—
1.2
—
—
0.8
209.7
204.8
—
373.1
156.1
806.5
10.4
(25.0 )
—
—
—
—
(79.8)
(38.2)
(117.0 )
161.7
48.8
166.7
141.9
$
494.7
369.4
374.6
(0.05)
$
0.43
0.38
$
0.88
0.44
1.32
$
$
$
20.7
(46.2 )
45.5
(180.6)
(117.0 )
528.9
463.3
356.5
(0.18)
1.48
1.30
Net Operating Earnings Available to Common Shareholders
(Non-GAAP)
$
169.6
Basic Average Common Shares Outstanding
GAAP Basic Earnings (Loss) Per Share
Adjustments to basic earnings (loss) per share
Non-GAAP Basic Net Operating Earnings Per Share
377.2
(0.41)
0.86
0.45
$
$
$
$
$
(1)Represents revenues not billed to impacted customers as a result of the Greater Lawrence Incident.
(2)Represents costs incurred associated with the retirement of Units 7 and 8 at Bailly Generating Station.
(3)Represents costs incurred for estimated third-party claims and related other expenses as a result of the Greater Lawrence Incident, net of insurance recoveries recorded.
(4)Represents a non-cash impairment of the Columbia of Massachusetts franchise rights as a result of recent events connected with the Greater Lawrence Incident.
(5)Represents a non-cash impairment of goodwill attributable to Columbia of Massachusetts as a result of recent events connected with the Greater Lawrence Incident.
(6)Income tax effect is calculated using the statutory tax rate by legal entity.
(7)2019 activity represents the non-deductible goodwill impairment (see footnote 5 above), non-deductible fines and penalties and adjustments to consolidated state deferred
taxes related to the Greater Lawrence Incident. 2018 activity represents adjustments to the impact of the Tax Cuts and Jobs Act of 2017 due to regulatory actions in 2018.
█ 26
UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
FORM 10-K
ANNUAL REPORT PURSUANT TO SECTION 13 OR 15(d)
OF THE SECURITIES EXCHANGE ACT OF 1934
For the fiscal year ended December 31, 2019
OR
TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d)
OF THE SECURITIES EXCHANGE ACT OF 1934
For the transition period from to
Commission file number 001-16189
NiSource Inc.
(Exact name of registrant as specified in its charter)
DE
(State or other jurisdiction of
incorporation or organization)
801 East 86th Avenue
Merrillville, IN
(Address of principal executive offices)
35-2108964
(I.R.S. Employer
Identification No.)
46410
(Zip Code)
Securities registered pursuant to Section 12(b) of the Act:
(877) 647-5990
(Registrant’s telephone number, including area code)
Title of Each Class
Common Stock, par value $0.01 per share
Depositary Shares, each representing a 1/1,000th ownership interest in a share of 6.50% Series B
Fixed-Rate Reset Cumulative Redeemable Perpetual Preferred Stock, par value $0.01 per share,
liquidation preference $25,000 per share and a 1/1,000th ownership interest in a share of Series
B-1 Preferred Stock, par value $0.01 per share, liquidation preference $0.01 per share
Securities registered pursuant to Section 12(g) of the Act: None
Trading
Symbol(s)
NI
NI PR B
Name of Each Exchange on
Which Registered
NYSE
NYSE
Indicate by check mark if the registrant is a well-known seasoned issuer, as defined in Rule 405 of the Securities Act. Yes
No
Indicate by check mark if the registrant is not required to file reports pursuant to Section 13 or 15(d) of the Act. Yes
No
Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of
1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to
such filing requirements for the past 90 days.
Yes
No
Indicate by check mark whether the registrant has submitted electronically every Interactive Data File required to be submitted pursuant to Rule
405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to
submit such files).
No
Yes
Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, a smaller reporting company,
or an emerging growth company. See the definition of “large accelerated filer,” “accelerated filer,” “smaller reporting company,” and "emerging
growth company" in Rule 12-b-2 of the Exchange Act.
Large Accelerated Filer
Accelerated Filer
Emerging Growth Company
Non-accelerated Filer
Smaller Reporting Company
If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with
any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act.
Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Act). Yes
No
The aggregate market value of the registrant's common stock, par value $0.01 per share (the "Common Stock") held by non-affiliates was
approximately $10,713,311,150 based upon the June 28, 2019, closing price of $28.80 on the New York Stock Exchange.
There were 382,263,348 shares of Common Stock outstanding as of February 18, 2020.
Documents Incorporated by Reference
Part III of this report incorporates by reference specific portions of the Registrant’s Notice of Annual Meeting and Proxy Statement relating to
the Annual Meeting of Stockholders to be held on May 19, 2020.
Page
No.
3
6
9
21
21
21
21
22
23
25
27
49
50
CONTENTS
Defined Terms
Part I
Item 1.
Business ..............................................................................................................................................
Item 1A. Risk Factors ........................................................................................................................................
Item 1B.
Unresolved Staff Comments...............................................................................................................
Item 2.
Properties ............................................................................................................................................
Item 3.
Legal Proceedings...............................................................................................................................
Item 4.
Mine Safety Disclosures .....................................................................................................................
Supplemental Item. Information about our Executive Officers
Item 5.
Market for Registrant’s Common Equity, Related Stockholder Matters and Issuer Purchases of Equity
Securities
Item 6.
Selected Financial Data ......................................................................................................................
Item 7.
Management’s Discussion and Analysis of Financial Condition and Results of Operations .............
Item 7A.
Quantitative and Qualitative Disclosures About Market Risk............................................................
Item 8.
Financial Statements and Supplementary Data ..................................................................................
Item 9.
Changes in and Disagreements With Accountants on Accounting and Financial Disclosure ............
125
Item 9A.
Controls and Procedures .....................................................................................................................
125
Item 9B.
Other Information ...............................................................................................................................
126
Item 10.
Directors, Executive Officers and Corporate Governance
Item 11.
Executive Compensation
128
128
Item 12.
Security Ownership of Certain Beneficial Owners and Management and Related Stockholder Matters
128
Item 13.
Certain Relationships and Related Transactions, and Director Independence
Item 14.
Principal Accounting Fees and Services
Item 15.
Exhibits, Financial Statement Schedules
Signatures
2
128
128
129
134
Part II
Part III
Part IV
Table of Contents
The following is a list of abbreviations or acronyms that are used in this report:
DEFINED TERMS
NiSource Subsidiaries, Affiliates and Former Subsidiaries
Columbia of Kentucky ..............................................................
Columbia Gas of Kentucky, Inc.
Columbia of Maryland ..............................................................
Columbia Gas of Maryland, Inc.
Columbia of Massachusetts ......................................................
Bay State Gas Company
Columbia of Ohio......................................................................
Columbia Gas of Ohio, Inc.
Columbia of Pennsylvania ........................................................
Columbia Gas of Pennsylvania, Inc.
Columbia of Virginia.................................................................
Company ................................................................................... NiSource Inc. and its subsidiaries, unless otherwise indicated
Columbia Gas of Virginia, Inc.
by the context
CPG (former subsidiary) ........................................................... Columbia Pipeline Group, Inc.
NIPSCO ....................................................................................
Northern Indiana Public Service Company LLC
NiSource ("we," "us" or "our") .................................................
NiSource Inc.
NiSource Corporate Services ....................................................
NiSource Corporate Services Company
Abbreviations
ACE........................................................................................... Affordable clean energy
AFUDC .....................................................................................
AMR.......................................................................................... Automatic meter reading
AMRP........................................................................................ Accelerated Main Replacement Program
AMT.......................................................................................... Alternative Minimum Tax
AOCI .........................................................................................
Accumulated Other Comprehensive Income
Allowance for funds used during construction
Accounting Standards Codification
ASC ...........................................................................................
ASU........................................................................................... Accounting Standards Update
ATM .......................................................................................... At-the-market
Board .........................................................................................
BTA........................................................................................... Build-transfer agreement
CAP ........................................................................................... Compliance Assurance Process
CCGT ........................................................................................
Combined Cycle Gas Turbine
Board of Directors
CCRs .........................................................................................
CEP............................................................................................ Capital Expenditure Program
CERCLA ...................................................................................
Coal Combustion Residuals
Comprehensive Environmental Response Compensation and
Liability Act (also known as Superfund)
DPA........................................................................................... Deferred prosecution agreement
DPU...........................................................................................
DSIC.......................................................................................... Distribution System Investment Charge
DSM ..........................................................................................
Department of Public Utilities
Demand Side Management
ECT ...........................................................................................
Environmental Cost Tracker
EERM........................................................................................
ELG ........................................................................................... Effluent Limitation Guidelines
EPA............................................................................................
EPS............................................................................................
FAC ...........................................................................................
FASB .........................................................................................
United States Environmental Protection Agency
Earnings per share
Fuel adjustment clause
Environmental Expense Recovery Mechanism
Financial Accounting Standards Board
3
Table of Contents
DEFINED TERMS
FERC.........................................................................................
FMCA........................................................................................ Federally Mandated Cost Adjustment
GAAP........................................................................................
GCA .......................................................................................... Gas cost adjustment
GCR ..........................................................................................
Federal Energy Regulatory Commission
Generally Accepted Accounting Principles
Gas cost recovery
GHG ..........................................................................................
GSEP ......................................................................................... Gas System Enhancement Program
GWh ..........................................................................................
Greenhouse gas
Gigawatt hours
IRIS ...........................................................................................
Infrastructure Replacement and Improvement Surcharge
IRP.............................................................................................
Infrastructure Replacement Program
IRS ............................................................................................
Internal Revenue Service
IURC .........................................................................................
Indiana Utility Regulatory Commission
LDCs .........................................................................................
LIBOR....................................................................................... London inter-bank offered rate
LIFO..........................................................................................
MA DOR ................................................................................... Massachusetts Department of Revenue
Massachusetts Business ............................................................ All of the assets being sold to, and liabilities being assumed by,
Local distribution companies
Last-in, first-out
MGP ..........................................................................................
Manufactured Gas Plant
MISO.........................................................................................
Midcontinent Independent System Operator
MMDth......................................................................................
Million dekatherms
MW ...........................................................................................
Megawatts
Eversource pursuant to the Asset Purchase Agreement
MWh .........................................................................................
NOL........................................................................................... Net Operating Loss
NTSB ........................................................................................ National Transportation Safety Board
NYMEX .................................................................................... The New York Mercantile Exchange
NYSE ........................................................................................ The New York Stock Exchange
OPEB ........................................................................................
Megawatt hours
Other Postretirement and Postemployment Benefits
PCB ...........................................................................................
PHMSA ..................................................................................... U.S. Department of Transportation Pipeline and Hazardous
Polychlorinated biphenyls
Materials Safety Administration
PISCC........................................................................................ Post-in-service carrying charges
PPA............................................................................................ Power Purchase Agreement
PSC............................................................................................
Public Service Commission
PTC ........................................................................................... Production Tax Credits
PUC ...........................................................................................
Public Utility Commission
Public Utilities Commission of Ohio
PUCO ........................................................................................
RCRA........................................................................................ Resource Conservation and Recovery Act
ROU .......................................................................................... Right of use
SAB ........................................................................................... Staff accounting bulletin
SAVE......................................................................................... Steps to Advance Virginia's Energy Plan
Separation.................................................................................. The separation of our natural gas pipeline, midstream and
storage business from our natural gas and electric utility
business accomplished through a pro rata distribution to holders
of our outstanding common stock of all the outstanding shares
of common stock of CPG. The separation was completed on
July 1, 2015.
Securities and Exchange Commission
SEC ...........................................................................................
4
Table of Contents
DEFINED TERMS
SMRP ........................................................................................
STRIDE..................................................................................... Strategic Infrastructure Development and Enhancement
Sugar Creek...............................................................................
TCJA ......................................................................................... Tax Cuts and Jobs Act of 2017
TDSIC ....................................................................................... Transmission, Distribution and Storage System Improvement
Safety Modification and Replacement Program
Sugar Creek electric generating plant
U.S. Attorney's Office ............................................................... U.S. Attorney's Office for the District of Massachusetts
VSCC ........................................................................................
WCE.......................................................................................... Whiting Clean Energy
Virginia State Corporation Commission
Charge
Note regarding forward-looking statements
This Annual Report on Form 10-K contains “forward-looking statements,” within the meaning of Section 27A of the Securities
Act of 1933, as amended (the "Securities Act"), and Section 21E of the Securities Exchange Act of 1934, as amended (the "Exchange
Act"). Investors and prospective investors should understand that many factors govern whether any forward-looking statement
contained herein will be or can be realized. Any one of those factors could cause actual results to differ materially from those
projected. These forward-looking statements include, but are not limited to, statements concerning our plans, strategies, objectives,
expected performance, expenditures, recovery of expenditures through rates, stated on either a consolidated or segment basis, and
any and all underlying assumptions and other statements that are other than statements of historical fact. All forward-looking
statements are based on assumptions that management believes to be reasonable; however, there can be no assurance that actual
results will not differ materially.
Factors that could cause actual results to differ materially from the projections, forecasts, estimates and expectations discussed in
this Annual Report on Form 10-K include, among other things, our debt obligations; any changes to our credit rating or the credit
rating of certain of our subsidiaries; our ability to execute our growth strategy; changes in general economic, capital and commodity
market conditions; pension funding obligations; economic regulation and the impact of regulatory rate reviews; our ability to
obtain expected financial or regulatory outcomes; our ability to adapt to, and manage costs related to, advances in technology;
any changes in our assumptions regarding the financial implications of the Greater Lawrence Incident; compliance with the
agreements entered into with the U.S. Attorney’s Office to settle the U.S. Attorney’s Office’s investigation relating to the Greater
Lawrence Incident; the pending sale of the Columbia of Massachusetts business, including the terms and closing conditions under
the Asset Purchase Agreement; potential incidents and other operating risks associated with our business; our ability to obtain
sufficient insurance coverage and whether such coverage will protect us against significant losses; the outcome of legal and
regulatory proceedings, investigations, incidents, claims and litigation; any damage to our reputation, including in connection with
the Greater Lawrence Incident; compliance with applicable laws, regulations and tariffs; compliance with environmental laws and
the costs of associated liabilities; fluctuations in demand from residential and commercial customers; economic conditions of
certain industries; the success of NIPSCO's electric generation strategy; the price of energy commodities and related transportation
costs; the reliability of customers and suppliers to fulfill their payment and contractual obligations; potential impairments of
goodwill or definite-lived intangible assets; changes in taxation and accounting principles; the impact of an aging infrastructure;
the impact of climate change; potential cyber-attacks; construction risks and natural gas costs and supply risks; extreme weather
conditions; the attraction and retention of a qualified workforce; the ability of our subsidiaries to generate cash; our ability to
manage new initiatives and organizational changes; the performance of third-party suppliers and service providers; changes in the
method for determining LIBOR and the potential replacement of the LIBOR benchmark interest rate; and other matters set forth
in Item 1A, “Risk Factors” of this report, many of which risks are beyond our control. In addition, the relative contributions to
profitability by each business segment, and the assumptions underlying the forward-looking statements relating thereto, may
change over time.
All forward-looking statements are expressly qualified in their entirety by the foregoing cautionary statements. We undertake no
obligation to, and expressly disclaim any such obligation to, update or revise any forward-looking statements to reflect changed
assumptions, the occurrence of anticipated or unanticipated events or changes to the future results over time or otherwise, except
as required by law.
5
Table of Contents
ITEM 1. BUSINESS
NISOURCE INC.
NiSource Inc. is an energy holding company under the Public Utility Holding Company Act of 2005 whose subsidiaries are fully
regulated natural gas and electric utility companies serving approximately 4.0 million customers in seven states. NiSource is the
successor to an Indiana corporation organized in 1987 under the name of NIPSCO Industries, Inc., which changed its name to
NiSource on April 14, 1999.
NiSource is one of the nation’s largest natural gas distribution companies, as measured by number of customers. NiSource’s
principal subsidiaries include NiSource Gas Distribution Group, Inc., a natural gas distribution holding company, and NIPSCO,
a gas and electric company. NiSource derives substantially all of its revenues and earnings from the operating results of these rate-
regulated businesses.
On September 13, 2018, a series of fires and explosions occurred in Lawrence, Andover and North Andover, Massachusetts related
to the delivery of natural gas by Columbia of Massachusetts (referred to herein as the “Greater Lawrence Incident”). The Greater
Lawrence Incident resulted in one fatality and a number of injuries, damaged multiple homes and businesses, and caused the
temporary evacuation of significant portions of each municipality. The Massachusetts Governor’s Office declared a state of
emergency, authorizing the Massachusetts DPU to order another utility company to coordinate the restoration of utility services
in Lawrence, Andover and North Andover. The incident resulted in the interruption of gas for approximately 7,500 gas meters,
the majority of which served residences and approximately 700 of which served businesses, and the interruption of other utility
service more broadly in the area. Columbia of Massachusetts has replaced the cast iron and bare steel gas pipeline system in the
affected area and restored service to nearly all of the gas meters. Refer to Note 6, "Goodwill and Other Intangible Assets," Note
19-C. "Legal Proceedings," and E. "Other Matters," in the Notes to Consolidated Financial Statements for more information.
On February 26, 2020, NiSource and Columbia of Massachusetts (together with NiSource, “Seller”) entered into an Asset Purchase
Agreement (the "Asset Purchase Agreement") with Eversource, a Massachusetts voluntary association. Upon the terms and subject
to the conditions set forth in the Asset Purchase Agreement, NiSource and Columbia of Massachusetts agreed to sell to Eversource,
with certain additions and exceptions: (1) substantially all of the assets of Columbia of Massachusetts and (2) all of the assets held
by any of Columbia of Massachusetts’ affiliates that primarily relate to the business of storing, distributing or transporting natural
gas to residential, commercial and industrial customers in Massachusetts, as conducted by Columbia of Massachusetts, and
Eversource agreed to assume certain liabilities of Columbia of Massachusetts and its affiliates. The liabilities assumed by Eversource
under the Asset Purchase Agreement do not include, among others, any liabilities arising out the Greater Lawrence Incident or
liabilities of Columbia of Massachusetts or its affiliates pursuant to civil claims for injury of persons or damage to property to the
extent such injury or damage occurs prior to the closing in connection with the Massachusetts Business. The Asset Purchase
Agreement provides for a purchase price of $1,100 million in cash, subject to adjustment based on Columbia of Massachusetts’
net working capital as of the closing. The closing of the transactions contemplated by the Asset Purchase Agreement is subject to
Hart-Scott-Rodino Antitrust Improvements Act of 1976 and regulatory approvals, resolution of certain proceedings before
governmental bodies and other conditions. For additional information, see Note 26, “Subsequent Event,” in the Notes to
Consolidated Financial Statements.
NiSource’s reportable segments are: Gas Distribution Operations and Electric Operations. The following is a summary of the
business for each reporting segment. Refer to Item 7, “Management’s Discussion and Analysis of Financial Condition and Results
of Operations” and Note 23, "Segments of Business," in the Notes to Consolidated Financial Statements for additional information
for each segment.
Gas Distribution Operations
Our natural gas distribution operations serve approximately 3.5 million customers in seven states and operate approximately 60,000
miles of pipeline located in our service areas described below. Through our wholly-owned subsidiary NiSource Gas Distribution
Group, Inc., we own six distribution subsidiaries that provide natural gas to approximately 2.7 million residential, commercial
and industrial customers in Ohio, Pennsylvania, Virginia, Kentucky, Maryland and Massachusetts. Additionally, we distribute
natural gas to approximately 839,000 customers in northern Indiana through our wholly-owned subsidiary NIPSCO.
Electric Operations
We generate, transmit and distribute electricity through our subsidiary NIPSCO to approximately 476,000 customers in 20 counties
in the northern part of Indiana and engage in wholesale and transmission transactions. NIPSCO owns and operates two coal-fired
electric generating stations: four units at R.M. Schahfer located in Wheatfield, IN and one unit at Michigan City located in Michigan
City, IN. The two operating facilities have a generating capacity of 2,080 MW. NIPSCO also owns and operates Sugar Creek, a
CCGT plant located in West Terre Haute, IN with generating capacity of 571 MW, three gas-fired generating units located at
NIPSCO’s coal-fired electric generating stations with a generating capacity of 186 MW and two hydroelectric generating plants
with a generating capacity of 10 MW: Oakdale located at Lake Freeman in Carroll County, IN and Norway located at Lake Schahfer
in White County, IN. These facilities provide for a total system operating generating capacity of 2,847 MW.
6
Table of Contents
ITEM 1. BUSINESS
NISOURCE INC.
In May 2018, NIPSCO completed the retirement of two coal-burning units (Units 7 and 8) at Bailly Generating Station, located
in Chesterton, IN. These units had a generating capacity of approximately 460 MW.
NIPSCO’s transmission system, with voltages from 69,000 to 765,000 volts, consists of 3,005 circuit miles. NIPSCO is
interconnected with five neighboring electric utilities. During the year ended December 31, 2019, NIPSCO generated 62.4% and
purchased 37.6% of its electric requirements.
NIPSCO participates in the MISO transmission service and wholesale energy market. MISO is a nonprofit organization created
in compliance with FERC regulations to improve the flow of electricity in the regional marketplace and to enhance electric
reliability. Additionally, MISO is responsible for managing energy markets, transmission constraints and the day-ahead, real-time,
FTR and ancillary markets. NIPSCO transferred functional control of its electric transmission assets to MISO, and transmission
service for NIPSCO occurs under the MISO Open Access Transmission Tariff.
Business Strategy
We focus our business strategy on our core, rate-regulated asset-based businesses with most of our operating income generated
from the rate-regulated businesses. Our utilities continue to move forward on core infrastructure and environmental investment
programs supported by complementary regulatory and customer initiatives across all seven states in which we operate. Our goal
is to develop strategies that benefit all stakeholders as we address changing customer conservation patterns, develop more
contemporary pricing structures, and embark on long-term investment programs. These strategies are intended to improve reliability
and safety, enhance customer service and reduce emissions while generating sustainable returns.
In its 2018 Integrated Resource Plan submission to the IURC, NIPSCO laid out a plan to retire the R.M. Schahfer Generating
Station (Units 14, 15, 17, and 18) by 2023 and Michigan City Generating Station (Unit 12) by 2028. These units represent 2,080
MW of generating capacity, equal to 72% of NIPSCO’s remaining capacity after the retirement of Bailly Units 7 and 8 in May of
2018. The current replacement plan includes renewable sources of energy, including wind, solar, and battery storage to be obtained
through a combination of NIPSCO ownership and PPAs. Refer to Note 19-E, "Other Matters," in the Notes to Consolidated
Financial Statements for further discussion of these plans.
Competition and Changes in the Regulatory Environment
The regulatory frameworks applicable to our operations, at both the state and federal levels, continue to evolve. These changes
have had and will continue to have an impact on our operations, structure and profitability. Management continually seeks new
ways to be more competitive and profitable in this environment.
The Gas Distribution Operations companies have pursued non-traditional revenue sources within the evolving natural gas
marketplace. These efforts include the sale of products and services upstream of the companies’ service territory, the sale of
products and services in the companies’ service territories, and gas supply cost incentive mechanisms for service to their core
markets. The upstream products are made up of transactions that occur between an individual Gas Distribution Operations company
and a buyer for the sales of unbundled or rebundled gas supply and capacity. The on-system services are offered by us to customers
and include products such as the transportation and balancing of gas on the Gas Distribution Operations company system. The
incentive mechanisms give the Gas Distribution Operations companies an opportunity to share in the savings created from such
situations as gas purchase prices paid below an agreed upon benchmark and their ability to reduce pipeline capacity charges with
their customers.
Increased efficiency of natural gas appliances and improvements in home building codes and standards has contributed to a long-
term trend of declining average use per customer. Residential usage for the year ended December 31, 2019 decreased primarily
due to warmer weather in our operating area compared to the prior year. While historically rate design at the distribution level has
been structured such that a large portion of cost recovery is based upon throughput rather than in a fixed charge, operating costs
are largely incurred on a fixed basis and do not fluctuate due to changes in customer usage. As a result, Gas Distribution Operations
have pursued changes in rate design to more effectively match recoveries with costs incurred. Each of the states in which Gas
Distribution Operations operate has different requirements regarding the procedure for establishing changes to rate design.
Columbia of Ohio restructured its rate design through a base rate proceeding and has adopted a decoupled rate design which more
closely links the recovery of fixed costs with fixed charges. Columbia of Massachusetts received regulatory approval of a decoupling
mechanism which adjusts revenues to an approved benchmark level through a volumetric adjustment factor. Columbia of Maryland
and Columbia of Virginia have regulatory approval for a revenue normalization adjustment for certain customer classes, a
decoupling mechanism whereby monthly revenues that exceed or fall short of approved levels are reconciled in subsequent months.
In a prior base rate proceeding, Columbia of Pennsylvania implemented a pilot residential weather normalization adjustment.
Columbia of Maryland, Columbia of Virginia and Columbia of Kentucky have had approval for a weather normalization adjustment
7
Table of Contents
ITEM 1. BUSINESS
NISOURCE INC.
for many years. In a prior gas base rate proceeding, NIPSCO implemented a higher fixed customer charge for residential and small
customer classes moving toward full straight fixed variable rate design.
Natural Gas Competition. Open access to natural gas supplies over interstate pipelines and the deregulation of the commodity
price of gas has led to tremendous change in the energy markets. LDC customers and marketers can purchase gas directly from
producers and marketers as an open, competitive market for gas supplies has emerged. This separation or “unbundling” of the
transportation and other services offered by pipelines and LDCs allows customers to purchase the commodity independent of
services provided by the pipelines and LDCs. The LDCs continue to purchase gas and recover the associated costs from their
customers. Our Gas Distribution Operations’ subsidiaries are involved in programs that provide customers the opportunity to
purchase their natural gas requirements from third parties and use our Gas Distribution Operations’ subsidiaries for transportation
services.
Gas Distribution Operations competes with investor-owned, municipal, and cooperative electric utilities throughout its service
areas as well as other regulated and unregulated natural gas intra and interstate pipelines and other alternate fuels, such as propane
and fuel oil. Gas Distribution Operations continues to be a strong competitor in the energy market as a result of strong customer
preference for natural gas. Competition with providers of electricity has traditionally been the strongest in the residential and
commercial markets of Kentucky, southern Ohio, central Pennsylvania and western Virginia due to comparatively low electric
rates. Natural gas competes with fuel oil and propane in the Massachusetts market mainly due to the installed base of fuel oil and
propane-based heating which has comprised a declining percentage of the overall market over the last few years. However, fuel
oil and propane are more viable in today’s oil market.
Electric Competition. Indiana electric utilities generally have exclusive service areas under Indiana regulations, and retail electric
customers in Indiana do not have the ability to choose their electric supplier. NIPSCO faces non-utility competition from other
energy sources, such as self-generation by large industrial customers and other distributed energy sources.
Seasonality
A significant portion of our operations are subject to seasonal fluctuations in sales. During the heating season, which is primarily
from November through March, revenues from gas sales are more significant, and during the cooling season, which is primarily
June through September, revenues from electric sales are more significant, than in other months.
Other Relevant Business Information
Our customer base is broadly diversified, with no single customer accounting for a significant portion of revenues.
As of December 31, 2019, we had 8,363 employees of whom 3,219 were subject to collective bargaining agreements. Collective
bargaining agreements for 96 employees are set to expire within one year.
For a listing of certain subsidiaries of NiSource refer to Exhibit 21.
We electronically file various reports with the SEC, including annual reports on Form 10-K, quarterly reports on Form 10-Q,
current reports on Form 8-K and amendments to such reports, as well as our proxy statements for the Company's annual meetings
of stockholders at http://www.sec.gov. Additionally, we make all SEC filings available without charge to the public on our web
site at http://www.nisource.com.
8
Table of Contents
ITEM 1A. RISK FACTORS
NISOURCE INC.
Our operations and financial results are subject to various risks and uncertainties, including those described below, that could
adversely affect our business, financial condition, results of operations, cash flows, and the trading price of our common stock.
We have substantial indebtedness which could adversely affect our financial condition.
Our business is capital intensive and we rely significantly on long-term debt to fund a portion of our capital expenditures and repay
outstanding debt, and on short-term borrowings to fund a portion of day-to-day business operations. We had total consolidated
indebtedness of $9,642.8 million outstanding as of December 31, 2019. Our substantial indebtedness could have important
consequences. For example, it could:
•
•
•
•
•
•
•
limit our ability to borrow additional funds or increase the cost of borrowing additional funds;
reduce the availability of cash flow from operations to fund working capital, capital expenditures and other general
corporate purposes;
limit our flexibility in planning for, or reacting to, changes in the business and the industries in which we operate;
lead parties with whom we do business to require additional credit support, such as letters of credit, in order for us to
transact such business;
place us at a competitive disadvantage compared to competitors that are less leveraged;
increase vulnerability to general adverse economic and industry conditions; and
limit our ability to execute on our growth strategy, which is dependent upon access to capital to fund our substantial
infrastructure investment program.
Some of our debt obligations contain financial covenants related to debt-to-capital ratios and cross-default provisions. Our failure
to comply with any of these covenants could result in an event of default, which, if not cured or waived, could result in the
acceleration of outstanding debt obligations.
A drop in our credit ratings could adversely impact our cash flows, results of operation, financial condition and liquidity.
The availability and cost of credit for our businesses may be greatly affected by credit ratings. The credit rating agencies periodically
review our ratings, taking into account factors such as our capital structure, earnings profile, and, in 2018 and 2019, the impacts
of the TCJA and the Greater Lawrence Incident. We are committed to maintaining investment grade credit ratings; however, there
is no assurance we will be able to do so in the future. Our credit ratings could be lowered or withdrawn entirely by a rating agency
if, in its judgment, the circumstances warrant. Any negative rating action could adversely affect our ability to access capital at
rates and on terms that are attractive. A negative rating action could also adversely impact our business relationships with suppliers
and operating partners, who may be less willing to extend credit or offer us similarly favorable terms as secured in the past under
such circumstances.
Certain of our subsidiaries have agreements that contain “ratings triggers” that require increased collateral in the form of cash, a
letter of credit or other forms of security for new and existing transactions if the credit ratings of our or certain of our subsidiaries
are dropped below investment grade. These agreements are primarily for insurance purposes and for the physical purchase or sale
of gas or power. As of December 31, 2019, the collateral requirement that would be required in the event of a downgrade below
the ratings trigger levels would amount to approximately $72.1 million. In addition to agreements with ratings triggers, there are
other agreements that contain “adequate assurance” or “material adverse change” provisions that could necessitate additional credit
support such as letters of credit and cash collateral to transact business.
If our or certain of our subsidiaries' credit ratings were downgraded, especially below investment grade, financing costs and the
principal amount of borrowings would likely increase due to the additional risk of our debt and because certain counterparties may
require additional credit support as described above. Such amounts may be material and could adversely affect our cash flows,
results of operations and financial condition. Losing investment grade credit ratings may also result in more restrictive covenants
and reduced flexibility on repayment terms in debt issuances, lower share price and greater stockholder dilution from common
equity issuances, in addition to reputational damage within the investment community.
We may not be able to execute our business plan or growth strategy, including utility infrastructure investments.
Business or regulatory conditions may result in us not being able to execute our business plan or growth strategy, including
identified, planned and other utility infrastructure investments. Our customer and regulatory initiatives may not achieve planned
9
Table of Contents
ITEM 1A. RISK FACTORS
NISOURCE INC.
results. Utility infrastructure investments may not materialize, may cease to be achievable or economically viable and may not be
successfully completed. Natural gas may cease to be viewed as an economically and environmentally attractive fuel. Certain
groups and governmental entities may continue to oppose natural gas delivery and infrastructure investments because of perceived
environmental impacts associated with the natural gas supply chain and end use. Energy conservation, energy efficiency, distributed
generation, energy storage, policies favoring electric heat over gas heat and other factors may reduce demand for natural gas and
energy. Any of these developments could adversely affect our results of operations and growth prospects. Even if our business
plan and growth strategy are executed, there is still risk of, among other things, human error in maintenance, installation or
operations, shortages or delays in obtaining equipment, and performance below expected levels (in addition to the other risks
discussed in this section).
Adverse economic and market conditions or increases in interest rates could materially and adversely affect our results of
operations, cash flows, financial condition and liquidity.
While the national economy is experiencing modest growth, we cannot predict how robust future growth will be or whether it
will be sustained. Deteriorating or sluggish economic conditions in our operating jurisdictions could adversely impact our ability
to maintain or grow our customer base and collect revenues from customers, which could reduce revenue growth and increase
operating costs. In addition, a rising interest rate environment may lead to higher borrowing costs, which may adversely impact
reported earnings, cost of capital and capital holdings. Rising interest rates and negative market or company events may also result
in a decrease in the price of our shares of common stock.
We rely on access to the capital markets to finance our liquidity and long-term capital requirements, including expenditures for
our utility infrastructure and to comply with future regulatory requirements, to the extent not satisfied by the cash flow generated
by our operations. We have historically relied on long-term debt and on the issuance of equity securities to fund a portion of our
capital expenditures and repay outstanding debt, and on short-term borrowings to fund a portion of day-to-day business operations.
Successful implementation of our long-term business strategies, including capital investment, is dependent upon our ability to
access the capital and credit markets, including the banking and commercial paper markets, on competitive terms and rates. An
economic downturn or uncertainty, market turmoil, changes in tax policy, challenges faced by financial institutions, changes in
our credit ratings, or a change in investor sentiment toward us or the utilities industry generally could adversely affect our ability
to raise additional capital or refinance debt. Reduced access to capital markets and/or increased borrowing costs could reduce
future net income and cash flows. Refer to Note 14, “Long-Term Debt,” in the Notes to Consolidated Financial Statements for
information related to outstanding long-term debt and maturities of that debt.
If any of these risks or uncertainties limit our access to the credit and capital markets or significantly increase our cost of capital,
it could limit our ability to implement, or increase the costs of implementing, our business plan, which, in turn, could materially
and adversely affect our results of operations, cash flows, financial condition and liquidity.
Capital market performance and other factors may decrease the value of benefit plan assets, which then could require
significant additional funding and impact earnings.
The performance of the capital markets affects the value of the assets that are held in trust to satisfy future obligations under defined
benefit pension and other postretirement benefit plans. We have significant obligations in these areas and hold significant assets
in these trusts as noted in Note 11, "Pension and Other Postretirement Benefits," in the Notes to Consolidated Financial Statements.
These assets are subject to market fluctuations and may yield uncertain returns, which fall below our projected rates of return. A
decline in the market value of assets may increase the funding requirements of the obligations under the defined benefit pension
and other postretirement benefit plans. Additionally, changes in interest rates affect the liabilities under these benefit plans; as
interest rates decrease, the liabilities increase, which could potentially increase funding requirements. Further, the funding
requirements of the obligations related to these benefits plans may increase due to changes in governmental regulations and
participant demographics, including increased numbers of retirements or changes in life expectancy assumptions. In addition,
lower asset returns result in increased expenses. Ultimately, significant funding requirements and increased pension or other
postretirement benefit plan expense could negatively impact our results of operations and financial position.
10
Table of Contents
ITEM 1A. RISK FACTORS
NISOURCE INC.
The majority of our revenues are subject to economic regulation and are exposed to the impact of regulatory rate reviews
and proceedings.
Most of our revenues are subject to economic regulation at either the federal or state level. As such, the revenues generated by us
are subject to regulatory review by the applicable federal or state authority. These rate reviews determine the rates charged to
customers and directly impact revenues. Our financial results are dependent on frequent regulatory proceedings in order to ensure
timely recovery of costs and investments. In addition to our ongoing regulatory proceedings, the recovery of the Greater Lawrence
pipeline replacement capital investment will be addressed in a future regulatory proceeding as discussed in Note 19, "Other
Commitments and Contingencies - E. Other Matters” in the Notes to Consolidated Financial Statements.
The outcomes of these proceedings are uncertain, potentially lengthy and could be influenced by many factors, some of which
may be outside of our control, including the cost of providing service, the necessity of expenditures, the quality of service, regulatory
interpretations, customer intervention, economic conditions and the political environment. Further, the rate orders are subject to
appeal, which creates additional uncertainty as to the rates that will ultimately be allowed to be charged for services. Additionally,
the costs of complying with current and future changes in environmental and federal pipeline safety laws and regulations are
expected to be significant, and their recovery through rates will also be contingent on regulatory approval.
Failure to adapt to advances in technology and manage the related costs could make us less competitive and negatively
impact our results of operations and financial condition.
A key element of our business model is that generating power at central station power plants achieves economies of scale and
produces power at a competitive cost. We continue to research, plan for, and implement new technologies that produce power or
reduce power consumption. These technologies include renewable energy, distributed generation, energy storage, and energy
efficiency. Advances in technology and changes in laws or regulations (including subsidization) are reducing the cost of these or
other alternative methods of producing power to a level that is competitive with that of most central station power electric production
or result in smaller-scale, more fuel efficient, and/or more cost-effective distributed generation. This could cause power sales to
decline and the value of our generating facilities to decline. New technologies may require us to make significant expenditures
to remain competitive and may result in the obsolescence of certain operating assets.
In addition, customers are increasingly expecting enhanced communications regarding their electric and natural gas services,
which, in some cases, may involve additional investments in technology. We also rely on technology to adequately maintain key
business records.
Our future success will depend, in part, on our ability to anticipate and successfully adapt to technological changes, to offer services
that meet customer demands and evolving industry standards, and to recover all, or a significant portion of, any unrecovered
investment in obsolete assets. A failure by us to effectively adapt to changes in technology and manage the related costs could
harm our ability to remain competitive in the marketplace for our products, services and processes and could have a material
adverse impact on our results of operations and financial condition.
The Greater Lawrence Incident has materially adversely affected and may continue to materially adversely affect our
financial condition, results of operations and cash flows.
In connection with the Greater Lawrence Incident, we have incurred and will incur various costs and expenses as set forth in Note
6, "Goodwill and Other Intangible Assets," Note 19, "Other Commitments and Contingencies - C. Legal Proceedings," and “- E.
Other Matters" in the Notes to Consolidated Financial Statements.
We are subject to inquiries and investigations by government authorities and regulatory agencies regarding the Greater Lawrence
Incident, including the Massachusetts DPU and the Massachusetts Attorney General's Office. We are cooperating with all inquiries
and investigations. In addition, on February 26, 2020, the Company and Columbia of Massachusetts entered into agreements with
the U.S. Attorney’s Office to resolve the U.S. Attorney’s Office’s investigation relating to the Greater Lawrence Incident, as
described further below.
As more information becomes known, management's estimates and assumptions regarding the costs and expenses to be incurred
and the financial impact of the Greater Lawrence Incident may change. A change in management’s estimates or assumptions could
result in an adjustment that would have a material impact on our financial condition, results of operations and cash flows during
the period in which such change occurred.
While we have recovered the full amount of our liability insurance coverage available under our policies, total expenses related
to the incident have exceeded such amount. Expenses in excess of our liability insurance coverage have materially adversely
affected and may continue to materially adversely affect our results of operations, cash flows and financial position.
11
Table of Contents
ITEM 1A. RISK FACTORS
NISOURCE INC.
We may also incur additional costs associated with the Greater Lawrence Incident, beyond the amount currently anticipated,
including in connection with investigations by regulators as well as civil litigation. Further, state or federal legislation may be
enacted that would require us to incur additional costs by mandating various changes, including changes to our operating practice
standards for natural gas distribution operations and safety. If we are unable to recover the capital cost of the gas pipeline replacement
in the impacted area or we incur a material amount of other costs that we are unable to recover through rates or offset through
operational or other cost savings, our financial condition, results of operations, and cash flows could be materially and adversely
affected.
Further, if it is determined in other matters that we did not comply with applicable statutes, regulations, rules, tariffs, or orders in
connection with the Greater Lawrence Incident or in connection with the operations or maintenance of our natural gas system, and
we are ordered to pay additional amounts in customer refunds, penalties, or other amounts, our financial condition, results of
operations, and cash flows could be materially and adversely affected.
Our settlement with the U.S. Attorney’s Office in respect of federal charges in connection with the Greater Lawrence
Incident may expose us to further penalties, liabilities and private litigation, and may impact our operations.
On February 26, 2020, the Company entered into a DPA and Columbia of Massachusetts entered into a plea agreement with the
U.S. Attorney’s Office to resolve the U.S. Attorney’s Office’s investigation relating to the Greater Lawrence Incident. Columbia
of Massachusetts’ plea agreement with the U.S. Attorney’s Office is subject to approval by the United States District Court for the
District of Massachusetts (the "Court"). If Columbia of Massachusetts’ guilty plea is not accepted by the Court or is withdrawn
for any reason, the U.S. Attorney's Office may, at its sole option, render the DPA null and void. See Note 19, “Other Commitments
and Contingencies - C. Legal Proceedings” in the Notes to Consolidated Financial Statements. The agreements impose various
compliance and remedial obligations on the Company and Columbia of Massachusetts. Failure to comply with the terms of these
agreements could result in further enforcement action by the U.S. Attorney’s Office, expose the Company and Columbia of
Massachusetts to penalties, financial or otherwise, and subjects the Company to further private litigation, each of which could
impact our operations and have a material adverse effect on our business.
The closing of the sale of the Massachusetts Business is subject to receipt of clearance and approval from various
governmental entities and other closing conditions that may not be satisfied or waived, and, in order to receive such
clearance, consent or approval, governmental entities may impose conditions, terms, obligations or restrictions that
Eversource is not obligated to accept in order to complete the transaction.
On February 26, 2020, NiSource, Columbia of Massachusetts and Eversource entered into the Asset Purchase Agreement providing
for the sale of the Massachusetts Business to Eversource. The Asset Purchase Agreement provides for various closing conditions,
including (a) the expiration or termination of the waiting period under the Hart-Scott-Rodino Antitrust Improvements Act of 1976,
(b) the receipt of the approval of the Massachusetts DPU (the “MDPU Approval”) and (c) the final resolution or termination of
all pending actions, claims and proceedings against Seller and its affiliates under the jurisdiction of the Massachusetts DPU and
all future, actions, claims and proceedings against Seller and its affiliates relating to the Greater Lawrence Incident under the
jurisdiction of the Massachusetts DPU.
The satisfaction of many of the closing conditions is beyond our control. We may not receive the required clearance and approvals
for the transaction or the required resolution with the Massachusetts DPU, or we may not receive them in a timely manner. In
addition, governmental entities could impose conditions, terms, obligations or restrictions as conditions for their approvals and as
conditions to resolve certain proceedings, and these may include substantial payments by us. Moreover, Eversource is not required
to agree to any conditions, terms, obligations or restrictions to obtain required clearance and approvals if such conditions, terms,
obligations or restrictions would reasonably be expected to constitute a “burdensome condition” as defined in the Asset Purchase
Agreement. There can be no assurance that regulators will not seek to impose conditions, terms, obligations or restrictions that
would constitute burdensome conditions.
If the closing conditions are not satisfied or there is a substantial delay in obtaining the required clearance and approvals, or
otherwise satisfying the closing conditions, the sale of the Massachusetts Business may not be completed, and we may lose some
or all of the intended benefits of the sale.
The sale of the Massachusetts Business poses risks and challenges that could negatively impact our business, and we may
not realize the expected benefits of the sale of the Massachusetts Business.
The sale of the Massachusetts Business involves separation or carve-out activities and costs and possible disputes with Eversource.
Following the sale, we may have continued financial liabilities with respect to the business conducted by Columbia of Massachusetts,
12
Table of Contents
ITEM 1A. RISK FACTORS
NISOURCE INC.
as we will be required to retain responsibility for, and indemnify Eversource against, certain liabilities, including liabilities for any
fines arising out of the Greater Lawrence Incident and liabilities of Columbia of Massachusetts or its affiliates pursuant to civil
claims for injury of persons or damage to property to the extent such injury or damage occurs prior to the closing in connection
with Columbia of Massachusetts’ business. It may also be difficult to determine whether a claim from a third party is our
responsibility, and we may expend substantial resources trying to determine whether we or Eversource has responsibility for the
claim.
If we do not realize the expected benefits of the sale of the Massachusetts Business, our consolidated financial condition, results
of operations and cash flows could be negatively impacted. The sale of the Massachusetts Business may result in a dilutive impact
to our future earnings if we are unable to offset the dilutive impact from the loss of revenue associated with the sale, which could
have a material adverse effect on our results of operations and financial condition.
The failure to complete the transactions contemplated by the Asset Purchase Agreement within the expected time frame
or at all could adversely affect our business, financial condition and results of operations and the price of our common
stock.
If the sale of the Massachusetts Business is not completed by October 26, 2020 (subject to up to two automatic 45-day extensions
under certain circumstances related to obtaining required regulatory approvals and resolution with the Massachusetts DPU), we
or Eversource may choose not to proceed with the transaction. Completion of the transaction is subject to risks, including the risks
that approval of the transaction by governmental entities will not be obtained or that certain other closing conditions will not be
satisfied. A failure to complete the transaction may result in negative publicity and a negative impression of us in the investment
community. Moreover, under the terms of the settlement with the U.S. Attorney’s Office, we will be obligated to use reasonable
best efforts to sell Columbia of Massachusetts’ business, and there is no assurance that we will be able to sell such business to a
third party on as favorable terms, if at all. The occurrence of any of these events, individually or in combination, could have a
material adverse effect on our results of operations, financial condition or the trading price of our common stock.
Our gas distribution activities, as well as generation, transmission and distribution of electricity, involve a variety of inherent
hazards and operating risks, including potential public safety risks.
Our gas distribution activities, as well as generation, transmission, and distribution of electricity, involve a variety of inherent
hazards and operating risks, including, but not limited to, gas leaks and over-pressurization, downed power lines, damage to our
infrastructure by third parties, outages, environmental spills, mechanical problems and other incidents, which could cause
substantial financial losses, as demonstrated in part by the Greater Lawrence Incident. In addition, these hazards and risks have
resulted and may in the future result in serious injury or loss of life to employees and/or the general public, significant damage to
property, environmental pollution, impairment of our operations, adverse regulatory rulings and reputational harm, which in turn
could lead to substantial losses for us. The location of pipeline facilities, or generation, transmission, substation and distribution
facilities near populated areas, including residential areas, commercial business centers and industrial sites, could increase the
level of damages resulting from such incidents. As with the Greater Lawrence Incident, certain incidents have subjected and may
in the future subject us to litigation or administrative or other legal proceedings from time to time, both civil and criminal, which
could result in substantial monetary judgments, fines, or penalties against us, be resolved on unfavorable terms, and require us to
incur significant operational expenses. The occurrence of incidents has in certain instances adversely affected and could in the
future adversely affect our reputation, cash flows, financial position and/or results of operations. We maintain insurance against
some, but not all, of these risks and losses.
We may be unable to obtain insurance on acceptable terms or at all. Our liability insurance coverage did not provide
protection against all significant losses as a result of the Greater Lawrence Incident and may not provide protection against
all significant losses in the future.
Our ability to obtain insurance, as well as the cost and coverage of such insurance, are affected by developments affecting our
business; international, national, state, or local events; and the financial condition of insurers. The insurance market is experiencing
a hardening environment due to reductions in commercial suppliers and the capacity they are willing to issue, increases in overall
demand for capacity, and a prevalence of severe losses. NiSource has been particularly affected by the current market conditions.
We have not been able to obtain liability insurance coverage at previously procured limits at rates that are acceptable to us. Insurance
coverage may not continue to be available at limits, rates or terms acceptable to us. The premiums we pay for our insurance
coverage have significantly increased as a result of market conditions and the accumulated loss ratio over the history of NiSource
operations, and we expect that they will continue to increase as a result of market conditions. In addition, our insurance is not
sufficient or effective under all circumstances and against all hazards or liabilities to which we are subject. For example, total
expenses related to the Greater Lawrence Incident have exceeded the total amount of liability coverage available under our policies.
13
Table of Contents
ITEM 1A. RISK FACTORS
NISOURCE INC.
Also, certain types of damages, expenses or claimed costs, such as fines and penalties, may be excluded under the policies. In
addition, insurers providing insurance to us may raise defenses to coverage under the terms and conditions of the respective
insurance policies that could result in a denial of coverage or limit the amount of insurance proceeds available to us. Any losses
for which we are not fully insured or that are not covered by insurance at all could materially adversely affect our results of
operations, cash flows, and financial position. For example, expenses related to the Greater Lawrence Incident that we are unable
to recover from liability or property insurance have materially adversely affected and may continue to materially adversely affect
our results of operations. For more information regarding our insurance programs in the context of the Greater Lawrence Incident,
see Note 19, "Other Commitments and Contingencies - C. Legal Proceedings," and " - E. Other Matters" in the Notes to Consolidated
Financial Statements.
The outcome of legal and regulatory proceedings, investigations, inquiries, claims and litigation related to our business
operations, including those related to the Greater Lawrence Incident, may have a material adverse effect on our results of
operations, financial position or liquidity.
We are involved in legal and regulatory proceedings, investigations, inquiries, claims and litigation in connection with our business
operations, including the Greater Lawrence Incident, the most significant of which are summarized in Note 19, “Other Commitments
and Contingencies” in the Notes to Consolidated Financial Statements. Our insurance does not cover all costs and expenses that
we have incurred and that we may incur in the future relating to the Greater Lawrence Incident, and may not fully cover other
incidents that may occur in the future. Due to the inherent uncertainty of the outcomes of such matters, there can be no assurance
that the resolution of any particular claim or proceeding would not have a material adverse effect on our results of operations,
financial position or liquidity. Certain matters in connection with the Greater Lawrence Incident have had or may have a material
impact as described in Note 19, "Other Commitments and Contingencies" in the Notes to Consolidated Financial Statements. If
one or more of such additional or other matters were decided against us, the effects could be material to our results of operations
in the period in which we would be required to record or adjust the related liability and could also be material to our cash flows
in the periods that we would be required to pay such liability.
We are exposed to significant reputational risks, which make us vulnerable to a loss of cost recovery, increased litigation
and negative public perception.
As a utility company, we are subject to adverse publicity focused on the reliability of our services, the speed with which we are
able to respond effectively to electric outages, natural gas leaks or events and related accidents and similar interruptions caused
by storm damage or other unanticipated events, as well as our own or third parties' actions or failure to act. We are also subject
to adverse publicity related to actual or perceived environmental impacts. If customers, legislators, or regulators have or develop
a negative opinion of us, this could result in less favorable legislative and regulatory outcomes or increased regulatory oversight,
increased litigation and negative public perception. The adverse publicity and investigations we experienced as a result of the
Greater Lawrence Incident may have an ongoing negative impact on the public’s perception of us. It is difficult to predict the
ultimate impact of this adverse publicity. The foregoing may have continuing adverse effects on our business, results of operations,
cash flow and financial condition.
Our businesses are subject to various laws, regulations and tariffs. We could be materially adversely affected if we fail to
comply with such laws, regulations and tariffs or with any changes in or new interpretations of such laws, regulations and
tariffs.
Our businesses are subject to various laws, regulations and tariffs, including, but not limited to, those relating to natural gas pipeline
safety, employee safety, the environment and our energy infrastructure. Existing laws, regulations and tariffs may be revised or
become subject to new interpretations, and new laws, regulations and tariffs may be adopted or become applicable to us and our
operations. In some cases, compliance with new laws, regulations and tariffs increases our costs. If we fail to comply with laws,
regulations and tariffs applicable to us or with any changes in or new interpretations of such laws, regulations or tariffs, our financial
condition, results of operations, regulatory outcomes and cash flows may be materially adversely affected.
Our businesses are regulated under numerous environmental laws. The cost of compliance with these laws, and changes
to or additions to, or reinterpretations of the laws, could be significant. Liability from the failure to comply with existing
or changed laws could have a material adverse effect on our business, results of operations, cash flows and financial
condition.
Our businesses are subject to extensive federal, state and local environmental laws and rules that regulate, among other things, air
emissions, water usage and discharges, GHG and waste products such as coal combustion residuals. Compliance with these legal
obligations require us to make expenditures for installation of pollution control equipment, remediation, environmental monitoring,
emissions fees, and permits at many of our facilities. These expenditures are significant, and we expect that they will continue to
14
Table of Contents
ITEM 1A. RISK FACTORS
NISOURCE INC.
be significant in the future. Furthermore, if we fail to comply with environmental laws and regulations or are found to have caused
damage to the environment or persons, that failure or harm may result in the assessment of civil or criminal penalties and damages
against us and injunctions to remedy the failure or harm.
Existing environmental laws and regulations may be revised and new laws and regulations seeking to change environmental
regulation of the energy industry may be adopted or become applicable to us, with an increased focus on both coal and natural gas
in recent years. Revised or additional laws and regulations may result in significant additional expense and operating restrictions
on our facilities or increased compliance costs, which may not be fully recoverable from customers through regulated rates and
could, therefore, impact our financial position, financial results and cash flow. Moreover, such costs could materially affect the
continued economic viability of one or more of our facilities.
An area of significant uncertainty and risk are the laws concerning emission of GHG. While we continue to reduce GHG emissions
through the retirement of coal-fired electric generation, priority pipeline replacement, energy efficiency, leak detection and repair,
and other programs, and expect to further reduce GHG emissions through increased use of renewable energy, GHG emissions are
currently an expected aspect of the electric and natural gas business. Revised or additional future GHG legislation and/or regulation
related to the generation of electricity or the extraction, production, distribution, transmission, storage and end use of natural gas
could materially impact our gas supply, financial position, financial results and cash flows.
Even in instances where legal and regulatory requirements are already known or anticipated, the original cost estimates for
environmental improvements, remediation of past environmental impact, or pollution reduction strategies and equipment can differ
materially from the amount ultimately expended. The actual future expenditures depend on many factors, including the nature and
extent of impact, the method of improvement, the cost of raw materials, contractor costs, and requirements established by
environmental authorities. Changes in costs and the ability to recover under regulatory mechanisms could affect our financial
position, financial results and cash flows.
A significant portion of the gas and electricity we sell is used by residential and commercial customers for heating and air
conditioning. Accordingly, fluctuations in weather, gas and electricity commodity costs and economic conditions impact
demand of our customers and our operating results.
Energy sales are sensitive to variations in weather. Forecasts of energy sales are based on “normal” weather, which represents a
long-term historical average. Significant variations from normal weather could have, and have had, a material impact on energy
sales. Additionally, residential usage, and to some degree commercial usage, is sensitive to fluctuations in commodity costs for
gas and electricity, whereby usage declines with increased costs, thus affecting our financial results. Lastly, residential and
commercial customers’ usage is sensitive to economic conditions and factors such as unemployment, consumption and consumer
confidence. Therefore, prevailing economic conditions affecting the demand of our customers may in turn affect our financial
results.
Our business operations are subject to economic conditions in certain industries.
Business operations throughout our service territories have been and may continue to be adversely affected by economic events
at the national and local level where it operates. In particular, sales to large industrial customers, such as those in the steel, oil
refining, industrial gas and related industries, may be impacted by economic downturns and geographic or technological shifts in
production or production methods. The U.S. manufacturing industry continues to adjust to changing market conditions including
international competition, increasing costs, and fluctuating demand for its products.
The implementation of NIPSCO’s electric generation strategy, including the retirement of its coal generation units, may
not achieve intended results.
On October 31, 2018, NIPSCO submitted its 2018 Integrated Resource Plan with the IURC setting forth its short- and long-term
electric generation plans in an effort to maintain affordability while providing reliable, flexible and cleaner sources of power. The
plan evaluated demand-side and supply-side resource alternatives to reliably and cost-effectively meet NIPSCO customers' future
energy requirements over the ensuing 20 years. The preferred option within the Integrated Resource Plan sets forth a schedule to
retire R.M. Schahfer Generating Station (Units 14, 15, 17, and 18) in 2023 and Michigan City Generating Station (Unit 12) in
2028. The current replacement plan includes renewable sources of energy, including wind, solar, and battery storage.
As part of this plan, NIPSCO has IURC approval for the Jordan Creek PPA for 400 MW, the Indiana Crossroads BTA for 300 MW
and the Rosewater BTA for 100 MW. Each is a separate facility and all MW are nameplate capacity. NIPSCO has filed a notice
with the IURC of its intention not to move forward with one of its approved PPAs due to the failure to meet a condition precedent
in the agreement as a result of local zoning restrictions.
15
Table of Contents
ITEM 1A. RISK FACTORS
NISOURCE INC.
There are inherent risks and uncertainties in executing the Integrated Resource Plan, including changes in market conditions,
regulatory approvals, environmental regulations, commodity costs and customer expectations, which may impede NIPSCO’s
ability to achieve the intended results. NIPSCO’s future success will depend, in part, on its ability to successfully implement its
long-term electric generation plans, to offer services that meet customer demands and evolving industry standards, and to recover
all, or a significant portion of, any unrecovered investment in obsolete assets. NIPSCO’s electric generation strategy could require
significant future capital expenditures, operating costs and charges to earnings that may negatively impact our financial position,
financial results and cash flows.
Fluctuations in the price of energy commodities or their related transportation costs or an inability to obtain an adequate,
reliable and cost-effective fuel supply to meet customer demands may have a negative impact on our financial results.
Our electric generating fleet is dependent on coal and natural gas for fuel, and our gas distribution operations purchase and resell
much of the natural gas we deliver to our customers. These energy commodities are vulnerable to price fluctuations and fluctuations
in associated transportation costs. From time to time, we have also used hedging in order to offset fluctuations in commodity
supply prices. We rely on regulatory recovery mechanisms in the various jurisdictions in order to fully recover the commodity
costs incurred in providing service. However, while we have historically been successful in the recovery of costs related to such
commodity prices, there can be no assurance that such costs will be fully recovered through rates in a timely manner.
In addition, we depend on electric transmission lines, natural gas pipelines, and other transportation facilities owned and operated
by third parties to deliver the electricity and natural gas we sell to wholesale markets, supply natural gas to our gas storage and
electric generation facilities, and provide retail energy services to customers. If transportation is disrupted, or if capacity is
inadequate, we may be unable to sell and deliver our gas and electric services to some or all of our customers. As a result, we may
be required to procure additional or alternative electricity and/or natural gas supplies at then-current market rates, which, if recovery
of related costs is disallowed, could have a material adverse effect on our businesses, financial condition, cash flows, results of
operations and/or prospects.
We are exposed to risk that customers will not remit payment for delivered energy or services, and that suppliers or
counterparties will not perform under various financial or operating agreements.
Our extension of credit is governed by a Corporate Credit Risk Policy, involves considerable judgment by our employees and is
based on an evaluation of a customer or counterparty’s financial condition, credit history and other factors. We monitor our credit
risk exposure by obtaining credit reports and updated financial information for customers and suppliers, and by evaluating the
financial status of our banking partners and other counterparties by reference to market-based metrics such as credit default swap
pricing levels, and to traditional credit ratings provided by the major credit rating agencies. Adverse economic conditions could
result in an increase in defaults by customers, suppliers and counterparties.
We have significant goodwill and definite-lived intangible assets. Impairments of goodwill and definite-lived intangible
assets related to Columbia of Massachusetts have resulted in significant charges to earnings for the quarter and year ended
December 31, 2019. Any future impairments of other goodwill could result in a significant charge to earnings in a future
period and negatively impact our compliance with certain covenants under financing agreements.
In accordance with GAAP, we test goodwill for impairment at least annually and review our definite-lived intangible assets for
impairment when events or changes in circumstances indicate its fair value might be below its carrying value. Goodwill is also
tested for impairment when factors, examples of which include reduced cash flow estimates, a sustained decline in stock price or
market capitalization below book value, indicate that the carrying value may not be recoverable.
We are required to record a charge in our financial statements for a period in which any impairment of our goodwill or definite-
lived intangible assets is determined, negatively impacting our results of operations. In connection with the preparation of our
financial statements for the year ended December 31, 2019, we conducted an impairment analysis for the goodwill and definite-
lived intangible assets (franchise rights) related to Columbia of Massachusetts and concluded that such goodwill and franchise
rights were impaired. As a result, we recorded an impairment charge of $204.8 million for such goodwill and an impairment charge
of $209.7 million for such franchise rights at December 31, 2019. For additional information, see Note 6, “Goodwill and Other
Intangible Assets,” in the Notes to Consolidated Financial Statements.
A significant charge in the future could impact the capitalization ratio covenant under certain financing agreements. We are subject
to a financial covenant under our revolving credit facility and term loan agreement, which require us to maintain a debt to
capitalization ratio that does not exceed 70%. A similar covenant in a 2005 private placement note purchase agreement requires
us to maintain a debt to capitalization ratio that does not exceed 75%. As of December 31, 2019, the ratio was 61.7%.
16
Table of Contents
ITEM 1A. RISK FACTORS
NISOURCE INC.
Changes in taxation and the ability to quantify such changes as well as challenges to tax positions could adversely affect
our financial results.
We are subject to taxation by the various taxing authorities at the federal, state and local levels where we do business. Legislation
or regulation which could affect our tax burden could be enacted by any of these governmental authorities. For example, the TCJA
includes numerous provisions that affect businesses, including changes to U.S. corporate tax rates, business-related exclusions,
and deductions and credits. The outcome of regulatory proceedings regarding the extent to which the effect of a change in corporate
tax rate will impact customers and the time period over which the impact will occur could significantly impact future earnings and
cash flows. Separately, a challenge by a taxing authority, changes in taxing authorities’ administrative interpretations, decisions,
policies and positions, our ability to utilize tax benefits such as carryforwards or tax credits, or a deviation from other tax-related
assumptions may cause actual financial results to deviate from previous estimates.
Changes in accounting principles may adversely affect our financial results.
Future changes in accounting rules and associated changes in regulatory accounting may negatively impact the way we record
revenues, expenses, assets and liabilities. These changes in accounting standards may adversely affect our financial condition and
results of operations.
Aging infrastructure may lead to disruptions in operations and increased capital expenditures and maintenance costs, all
of which could negatively impact our financial results.
We have risks associated with aging infrastructure, including our gas infrastructure assets. These risks can be driven by threats
such as, but not limited to, internal corrosion, external corrosion and stress corrosion cracking. The age of these assets may result
in a need for replacement, a higher level of maintenance costs, or unscheduled outages, despite efforts by us to properly maintain
or upgrade these assets through inspection, scheduled maintenance and capital investment. In addition, the nature of the information
available on aging infrastructure assets, which in some cases is incomplete, may make inspections, maintenance, upgrading and
replacement of the assets particularly challenging. Additionally, missing or incorrect infrastructure data may lead to (1) difficulty
properly locating facilities, which can result in excavator damage and operational or emergency response issues, and (2)
configuration and control risks associated with the modification of system operating pressures in connection with turning off or
turning on service to customers, which can result in unintended outages or operating pressures. Also, additional maintenance and
inspections are required in some instances in order to improve infrastructure information and records and address emerging
regulatory or risk management requirements, which increases our costs. The failure to operate these assets as desired could result
in gas leaks and other incidents and in our inability to meet firm service obligations, which could adversely impact revenues, and
could also result in increased capital expenditures and maintenance costs, which, if not fully recovered from customers, could
negatively impact our financial results.
The impacts of climate change, natural disasters, acts of terrorism, accidents or other catastrophic events may disrupt
operations and reduce the ability to service customers.
A disruption or failure of natural gas distribution systems, or within electric generation, transmission or distribution systems, in
the event of a major hurricane, tornado, terrorist attack, cyber-attack (as further detailed below), accident or other catastrophic
event could cause delays in completing sales, providing services, or performing other critical functions. We have experienced
disruptions in the past from hurricanes and tornadoes and other events of this nature. The occurrence of such events could adversely
affect our financial position and results of operations. In accordance with customary industry practice, we maintain insurance
against some, but not all, of these risks and losses. There is also a concern that climate change may exacerbate the risks to physical
infrastructure. Such risks include heat stresses to power lines, storms that damage infrastructure, lake and sea level changes that
affect the manner in which services are currently provided, droughts or other stresses on water used to supply services, and other
extreme weather conditions. Climate change and the costs that may be associated with its impacts have the potential to affect our
business in many ways, including increasing the costs we incur in providing our products and services, impacting the demand for
and consumption of our products and services (due to change in both costs and weather patterns), and affecting the economic
health of the regions in which we operate.
17
Table of Contents
ITEM 1A. RISK FACTORS
NISOURCE INC.
A cyber-attack on any of our or certain third-party computer systems upon which we rely may adversely affect our ability
to operate and could lead to a loss or misuse of confidential and proprietary information or potential liability.
We are reliant on technology to run our business, which is dependent upon financial and operational computer systems to process
critical information necessary to conduct various elements of our business, including the generation, transmission and distribution
of electricity, operation of our gas pipeline facilities and the recording and reporting of commercial and financial transactions to
regulators, investors and other stakeholders. In addition to general information and cyber risks that all large corporations face
(e.g., malware, unauthorized access attempts, phishing attacks, malicious intent by insiders and inadvertent disclosure of sensitive
information), the utility industry faces evolving and increasingly complex cybersecurity risks associated with protecting sensitive
and confidential customer information, electric grid infrastructure, and natural gas infrastructure. Deployment of new business
technologies represents a new and large-scale opportunity for attacks on our information systems and confidential customer
information, as well as on the integrity of the energy grid and the natural gas infrastructure. Increasing large-scale corporate attacks
in conjunction with more sophisticated threats continue to challenge power and utility companies. Any failure of our computer
systems, or those of our customers, suppliers or others with whom we do business, could materially disrupt our ability to operate
our business and could result in a financial loss and possibly do harm to our reputation.
Additionally, our information systems experience ongoing, often sophisticated, cyber-attacks by a variety of sources, including
foreign sources, with the apparent aim to breach our cyber-defenses. Although we attempt to maintain adequate defenses to these
attacks and work through industry groups and trade associations to identify common threats and assess our countermeasures, a
security breach of our information systems, or a security breach of the information systems of our customers, suppliers or others
with whom we do business, could (i) impact the reliability of our generation, transmission and distribution systems and potentially
negatively impact our compliance with certain mandatory reliability standards, (ii) subject us to reputational and other harm or
liabilities associated with theft or inappropriate release of certain types of information such as system operating information or
information, personal or otherwise, relating to our customers or employees, (iii) impact our ability to manage our businesses, and/
or (iv) subject us to legal and regulatory proceedings and claims from third parties, in addition to remediation costs, any of which,
in turn, could have a material adverse effect on our businesses, cash flows, financial condition, results of operations and/or prospects.
Although we do maintain cyber insurance, it is possible that such insurance will not adequately cover any losses or liabilities we
may incur as a result of any cybersecurity-related litigation.
Our capital projects and programs subject us to construction risks and natural gas costs and supply risks, and require
numerous permits, approvals and certificates from various governmental agencies.
Our business requires substantial capital expenditures for investments in, among other things, capital improvements to our electric
generating facilities, electric and natural gas distribution infrastructure, natural gas storage, and other projects, including projects
for environmental compliance. We are engaged in intrastate natural gas pipeline modernization programs to maintain system
integrity and enhance service reliability and flexibility. NIPSCO also is currently engaged in a number of capital projects, including
environmental improvements to its electric generating stations, the construction of new transmission facilities, and new projects
related to renewable energy. As we undertake these projects and programs, we may be unable to complete them on schedule or
at the anticipated costs. Additionally, we may construct or purchase some of these projects and programs to capture anticipated
future growth in natural gas production, which may not materialize, and may cause the construction to occur over an extended
period of time.
Our existing and planned capital projects require numerous permits, approvals and certificates from federal, state, and local
governmental agencies. If there is a delay in obtaining any required regulatory approvals or if we fail to obtain or maintain any
required approvals or to comply with any applicable laws or regulations, we may not be able to construct or operate our facilities,
we may be forced to incur additional costs, or we may be unable to recover any or all amounts invested in a project. We also may
not receive the anticipated increases in revenue and cash flows resulting from such projects and programs until after their completion.
Other construction risks include changes in costs of materials, equipment, commodities or labor (including changes to tariffs on
materials), delays caused by construction incidents or injuries, work stoppages, shortages in qualified labor, poor initial cost
estimates, unforeseen engineering issues, the ability to obtain necessary rights-of-way, easements and transmissions connections
and general contractors and subcontractors not performing as required under their contracts.
To the extent that delays occur, costs become unrecoverable, or we otherwise become unable to effectively manage and complete
our capital projects, our results of operations, cash flows, and financial condition may be adversely affected.
Sustained extreme weather conditions may negatively impact our operations.
We conduct our operations across a wide geographic area subject to varied and potentially extreme weather conditions, which may
from time to time persist for sustained periods of time. Despite preventative maintenance efforts, persistent weather related stress
18
Table of Contents
ITEM 1A. RISK FACTORS
NISOURCE INC.
on our infrastructure may reveal weaknesses in our systems not previously known to us or otherwise present various operational
challenges across all business segments. Further, adverse weather may affect our ability to conduct operations in a manner that
satisfies customer expectations or contractual obligations, including by causing service disruptions.
Failure to attract and retain an appropriately qualified workforce, and maintain good labor relations, could harm our
results of operations.
We operate in an industry that requires many of our employees to possess unique technical skill sets. Events such as an aging
workforce without appropriate replacements, the mismatch of skill sets to future needs, or the unavailability of contract resources
may lead to operating challenges or increased costs. These operating challenges include lack of resources, loss of knowledge, and
a lengthy time period associated with skill development. In addition, current and prospective employees may determine that they
do not wish to work for us due to market, economic, employment and other conditions. Failure to hire and retain qualified
employees, including the ability to transfer significant internal historical knowledge and expertise to the new employees, may
adversely affect our ability to manage and operate our business. If we are unable to successfully attract and retain an appropriately
qualified workforce, safety, service reliability, customer satisfaction and our results of operations could be adversely affected.
Some of our employees are subject to collective bargaining agreements. Our collective bargaining agreements are generally
negotiated on an operating company basis. Any failure to reach an agreement on new labor contracts or to negotiate these labor
contracts might result in strikes, boycotts or other labor disruptions. Labor disruptions, strikes or significant negotiated wage and
benefit increases, whether due to union activities, employee turnover or otherwise, could have a material adverse effect on our
businesses, results of operations and/or cash flows.
We are a holding company and are dependent on cash generated by our subsidiaries to meet our debt obligations and pay
dividends on our stock.
We are a holding company and conduct our operations primarily through our subsidiaries, which are separate and distinct legal
entities. Substantially all of our consolidated assets are held by our subsidiaries. Accordingly, our ability to meet our debt obligations
or pay dividends on our common stock and preferred stock is largely dependent upon cash generated by these subsidiaries. In the
event a major subsidiary is not able to pay dividends or transfer cash flows to us, our ability to service our debt obligations or pay
dividends could be negatively affected.
If we cannot effectively manage new initiatives and organizational changes, we will be unable to address the opportunities
and challenges presented by our strategy and the business and regulatory environment.
In order to execute on our sustainable growth strategy and enhance our culture of ongoing continuous improvement, we must
effectively manage the complexity and frequency of new initiatives and organizational changes. If we are unable to make decisions
quickly, assess our opportunities and risks, and implement new governance, managerial and organizational processes as needed
to execute our strategy in this increasingly dynamic and competitive business and regulatory environment, our financial condition,
results of operations and relationships with our business partners, regulators, customers and stockholders may be negatively
impacted.
We outsource certain business functions to third-party suppliers and service providers, and substandard performance by
those third parties could harm our business, reputation and results of operations.
Utilities rely on extensive networks of business partners and suppliers to support critical enterprise capabilities across their
organizations. Global metrics indicate that deliveries from suppliers are slowing and that labor shortages are occurring in the energy
sector. We outsource certain services to third parties in areas including construction services, information technology, materials,
fleet, environmental, operational services and other areas. Outsourcing of services to third parties could expose us to inferior
service quality or substandard deliverables, which may result in non-compliance (including with applicable legal requirements
and industry standards), interruption of service or accidents, or reputational harm, which could negatively impact our results of
operations. If any difficulties in the operations of these third-party suppliers and service providers, including their systems, were
to occur, they could adversely affect our results of operations, or adversely affect our ability to work with regulators, unions,
customers or employees.
Changes in the method for determining LIBOR and the potential replacement of the LIBOR benchmark interest rate could
adversely affect our business, financial condition, results of operations and cash flows.
Some of our indebtedness, including borrowings under our revolving credit agreement and term loan agreement, bears interest at
a variable rate based on LIBOR. From time to time, we also enter into hedging instruments to manage our exposure to fluctuations
in the LIBOR benchmark interest rate. In addition, these hedging instruments, as well as hedging instruments that our subsidiaries
19
Table of Contents
ITEM 1A. RISK FACTORS
NISOURCE INC.
use for hedging natural gas price and basis risk, rely on LIBOR-based rates to calculate interest accrued on certain payments that
may be required to be made under these agreements, such as late payments or interest accrued if any cash collateral should be held
by a counterparty. Any changes announced by regulators in the method pursuant to which the LIBOR rates are determined may
result in a sudden or prolonged increase or decrease in the reported LIBOR rates. If that were to occur, the level of interest payments
we incur may change.
In July 2017, the United Kingdom Financial Conduct Authority (“FCA”), which regulates LIBOR, announced that the FCA intends
to stop compelling banks to submit rates for the calculation of LIBOR after 2021. It is not possible to predict the effect of these
changes, other reforms or the establishment of alternative reference rates in the United Kingdom or elsewhere. In the United States,
efforts to identify a set of alternative U.S. dollar reference interest rates include proposals by the Alternative Reference Rates
Committee of the Federal Reserve Board and the Federal Reserve Bank of New York. The Alternative Reference Rates Committee
has proposed the Secured Overnight Financing Rate ("SOFR") as its recommended alternative to LIBOR, and the Federal Reserve
Bank of New York began publishing SOFR rates in April 2018. SOFR is intended to be a broad measure of the cost of borrowing
cash overnight that is collateralized by U.S. Treasury securities. However, because SOFR is a broad U.S. Treasury repurchase
agreement financing rate that represents overnight secured funding transactions, it differs fundamentally from LIBOR. For example,
SOFR is a secured overnight rate, while LIBOR is an unsecured rate that represents interbank funding over different maturities.
In addition, because SOFR is a transaction-based rate, it is backward-looking, whereas LIBOR is forward-looking. Because of
these and other differences, there is no assurance that SOFR will perform in the same way as LIBOR would have performed at
any time, and there is no guarantee that it is a comparable substitute for LIBOR. SOFR may fail to gain market acceptance.
In addition, although certain of our LIBOR based obligations provide for alternative methods of calculating the interest rate payable
on certain of our obligations if LIBOR is not reported, which include, without limitation, requesting certain rates from major
reference banks in London or New York, uncertainty as to the extent and manner of future changes may result in interest rates and/
or payments that are higher than, lower than or that do not otherwise correlate over time with, the interest rates or payments that
would have been made on our obligations if a LIBOR-based rate was available in its current form.
20
Table of Contents
ITEM 1B. UNRESOLVED STAFF COMMENTS
NISOURCE INC.
None.
ITEM 2. PROPERTIES
Discussed below are the principal properties held by us and our subsidiaries as of December 31, 2019.
Gas Distribution Operations
Refer to Item 1, "Business - Gas Distribution Operations" of this report for further information on Gas Distribution Operations
properties.
Electric Operations
Refer to Item 1, "Business - Electric Operations" of this report for further information on Electric Operations properties.
Corporate and Other Operations
We own the Southlake Complex, our 325,000 square foot headquarters building located in Merrillville, Indiana.
Character of Ownership
Our principal properties and our subsidiaries principal properties are owned free from encumbrances, subject to minor exceptions,
none of which are of such a nature as to impair substantially the usefulness of such properties. Many of our subsidiary offices in
various communities served are occupied under leases. All properties are subject to routine liens for taxes, assessments and
undetermined charges (if any) incidental to construction. It is our practice to regularly pay such amounts, as and when due, unless
contested in good faith. In general, the electric lines, gas pipelines and related facilities are located on land not owned by us or
our subsidiaries, but are covered by necessary consents of various governmental authorities or by appropriate rights obtained from
owners of private property. We do not, however, generally have specific easements from the owners of the property adjacent to
public highways over, upon or under which our electric lines and gas distribution pipelines are located. At the time each of the
principal properties were purchased, a title search was made. In general, no examination of titles as to rights-of-way for electric
lines, gas pipelines or related facilities was made, other than examination, in certain cases, to verify the grantors’ ownership and
the lien status thereof.
ITEM 3. LEGAL PROCEEDINGS
For a description of our legal proceedings, see Note 19-C "Legal Proceedings" in the Notes to Consolidated Financial Statements.
ITEM 4. MINE SAFETY DISCLOSURES
Not applicable.
21
Table of Contents
SUPPLEMENTAL ITEM. INFORMATION ABOUT OUR EXECUTIVE OFFICERS
NISOURCE INC.
The following is a list of our executive officers, including their names, ages, offices held and other recent business experience.
Name
Joseph Hamrock ..........
Age
Office(s) Held in Past 5 Years
56 President and Chief Executive Officer of NiSource since July 2015.
Executive Vice President and Group Chief Executive Officer of NiSource from May
2012 to July 2015.
Donald E. Brown .........
48 Executive Vice President of NiSource since May 2015.
Chief Financial Officer of NiSource since July 2015.
Treasurer of NiSource from July 2015 to June 2016.
Peter T. Disser..............
51 Vice President, Internal Audit of NiSource since January 2019.
Vice President and Chief Financial Officer of UGI Utilities, a division of UGI Corporation
(gas and electric utility company) from 2010 to March 2015.
Chief Operating Officer of NiSource from September 2018 to December 2018.
Vice President, Audit of NiSource from November 2017 to September 2018.
Vice President, Planning and Analysis of NiSource from June 2016 to November 2017.
Vice President, Strategy and Planning of NiSource Corporate Services Company from
July 2015 to May 2016.
Chief Financial Officer of NIPSCO from 2012 to June 2015.
Carrie J. Hightman.......
62 Executive Vice President and Chief Legal Officer of NiSource since 2007.
Kenneth E. Keener.......
55 Senior Vice President and Chief Human Resources Officer of NiSource since August
2019.
Charles E. Shafer, II ....
50 Senior Vice President and Chief Safety Officer of NiSource since October 2019.
Vice President, Talent and Organizational Effectiveness of NiSource Corporate Services
Company from June 2012 to July 2019.
Senior Vice President, Gas Engineering and Gas Support Services of NiSource Corporate
Services Company from January 2019 to September 2019.
Senior Vice President, Customer Services and New Business of NiSource Corporate
Services Company from May 2016 through December 2018.
Vice President, Engineering and Construction of NiSource Corporate Services Company
from June 2012 to May 2016.
Violet G. Sistovaris......
58 Executive Vice President and President, NIPSCO of NiSource since July 2015.
Suzanne K. Surface .....
55 Chief Services Officer of NiSource since January 2019.
Senior Vice President and Chief Information Officer of NiSource from May 2014 to June
2015.
Vice President, Audit of NiSource from September 2018 to December 2018.
Vice President, Transformation Office of NiSource from August 2018 to September 2018.
Vice President, Corporate Services Customer Value of NiSource from November 2017
to August 2018.
Vice President, Audit of NiSource from July 2015 to November 2017.
Vice President, Regulatory Strategy and Support of NiSource Corporate Services
Company from July 2009 to June 2015.
Pablo A. Vegas.............
46 Executive Vice President and President, Gas Utilities of NiSource since January 2019.
Executive Vice President and Chief Restoration Officer of NiSource from September
2018 to December 2018.
Executive Vice President, Gas Business Segment and Chief Customer Officer of
NiSource from May 2017 to September 2018.
Executive Vice President and President, Columbia Gas Group from May 2016 to May
2017.
President and Chief Operating Officer of American Electric Power Company of Ohio
from May 2012 to May 2016.
22
Table of Contents
PART II
ITEM 5. MARKET FOR REGISTRANT’S COMMON EQUITY, RELATED STOCKHOLDER MATTERS AND ISSUER
PURCHASES OF EQUITY SECURITIES
NISOURCE INC.
NiSource’s common stock is listed and traded on the New York Stock Exchange under the symbol “NI.”
Holders of shares of NiSource’s common stock are entitled to receive dividends if and when declared by NiSource’s Board out
of funds legally available, subject to the prior dividend rights of holders of our preferred stock or the depositary shares representing
such preferred stock outstanding, and if full dividends have not been declared and paid on all outstanding shares of preferred stock
in any dividend period, no dividend may be declared or paid or set aside for payment on our common stock. The policy of the
Board has been to declare cash dividends on a quarterly basis payable on or about the 20th day of February, May, August, and
November. At its January 31, 2020 meeting, the Board declared a quarterly common dividend of $0.21 per share, payable on
February 20, 2020 to holders of record on February 11, 2020.
Although the Board currently intends to continue the payment of regular quarterly cash dividends on common shares, the timing
and amount of future dividends will depend on the earnings of NiSource’s subsidiaries, their financial condition, cash requirements,
regulatory restrictions, any restrictions in financing agreements and other factors deemed relevant by the Board. There can be no
assurance that NiSource will continue to pay such dividends or the amount of such dividends.
As of February 18, 2020, NiSource had 18,868 common stockholders of record and 382,263,348 shares outstanding.
The graph below compares the cumulative total shareholder return of NiSource’s common stock for the last five years with the
cumulative total return for the same period of the S&P 500 and the Dow Jones Utility indices. On July 1, 2015, NiSource completed
the Separation. Following the Separation, NiSource retained no ownership interest in CPG. The Separation is treated as a special
dividend for purposes of calculating the total shareholder return, with the then-current market value of the distributed shares being
deemed to have been reinvested on the Separation date in shares of NiSource common stock. A vertical line is included on the
graph below to identify the periods before and after the Separation.
23
Table of Contents
PART II
ITEM 5. MARKET FOR REGISTRANT’S COMMON EQUITY, RELATED STOCKHOLDER MATTERS AND ISSUER
PURCHASES OF EQUITY SECURITIES
NISOURCE INC.
The foregoing performance graph is being furnished as part of this annual report solely in accordance with the requirement under
Rule 14a-3(b)(9) to furnish stockholders with such information, and therefore, shall not be deemed to be filed or incorporated by
reference into any filings by NiSource under the Securities Act or the Exchange Act.
The total shareholder return for NiSource common stock and the two indices is calculated from an assumed initial investment of
$100 and assumes dividend reinvestment, including the impact of the distribution of CPG common stock in the Separation.
24
Table of Contents
ITEM 6. SELECTED FINANCIAL DATA
NISOURCE INC.
The selected data presented below as of and for the five years ended December 31, 2019, are derived from our Consolidated
Financial Statements. The data should be read together with the Consolidated Financial Statements including the related notes
thereto included in Item 8 of this Form 10-K.
Year Ended December 31, (in millions except per share data)
2019
2018
2017
2016
2015
Statement of Income Data:
Total Operating Revenues
$
5,208.9
$
5,114.5
$
4,874.6
$
4,492.5
$
4,651.8
Net Income (Loss) Available to Common Shareholders
328.0
(65.6)
128.5
331.5
198.6
Balance Sheet Data:
Total Assets
Capitalization
Stockholders’ equity
Long-term debt, excluding amounts due within one year
Total Capitalization
Per Share Data:
Basic Earnings (Loss) Per Share ($)
Diluted Earnings (Loss) Per Share ($)
Other Data:
Dividends declared per common share ($)
Common shares outstanding at the end of the year (in thousands)
Number of common stockholders
Dividends declared per Series A preferred share ($)
Dividends declared per Series B preferred share ($)
Capital expenditures
Number of employees
22,659.8
21,804.0
19,961.7
18,691.9
17,492.5
5,986.7
7,856.2
13,842.9
0.88
0.87
0.80
382,136
18,725
56.50
1,674.65
1,867.8
8,363
$
$
$
$
$
$
$
$
$
$
$
$
$
$
5,750.9
7,105.4
4,320.1
7,512.2
12,856.3
$
11,832.3
0.39
0.39
0.70
337,016
21,009
(0.18) $
(0.18) $
0.78
$
372,363
19,889
28.88
$
— $
$
$
$
$
4,071.2
6,058.2
10,129.4
1.02
1.01
0.64
323,160
22,272
$
$
$
$
— $
— $
— $
— $
3,843.5
5,948.5
9,792.0
0.63
0.63
0.83
319,110
30,190
—
—
1,814.6
$
1,753.8
$
1,490.4
$
1,367.5
8,087
8,175
8,007
7,596
• During 2019, we recorded a loss of approximately $284 million for third-party claims and approximately $154 million for
other incident-related expenses in connection with the Greater Lawrence Incident. Columbia of Massachusetts recorded $665
million for insurance recoveries through December 31, 2019. For additional information, see Note 19-C, "Legal Proceedings,"
and E, "Other Matters" in the Notes to Consolidated Financial Statements.
• During the fourth quarter of 2019, we recorded an impairment charge of $204.8 million for goodwill and an impairment
charge of $209.7 million for franchise rights, in each case related to Columbia of Massachusetts. For additional information,
see Note 6, “Goodwill and Other Intangible Assets,” in the Notes to Consolidated Financial Statements.
• During the third quarter of 2019, we closed our placement of $750.0 million of 2.95% senior unsecured notes maturing in
2029.
• During the second quarter of 2018, we completed the sale of 24,964,163 shares of $0.01 par value common stock at a price
of $24.28 per share in a private placement to selected institutional and accredited investors and issued 400,000 shares of
Series A preferred stock resulting in $400.0 million of gross proceeds or $393.9 million of net proceeds, after deducting
commissions and sales expenses. Additionally, in the fourth quarter of 2018, we issued 20,000 shares of Series B preferred
stock resulting in $500.0 million of gross proceeds or $486.1 million of net proceeds, after deducting commissions and sales
expenses.
• During 2018, we recorded a loss of approximately $757 million for third-party claims and approximately $266 million for
other incident-related expenses in connection with the Greater Lawrence Incident. Columbia of Massachusetts recorded $135
million for insurance recoveries through December 31, 2018. For additional information, see Note 19-C, "Legal Proceedings,"
and E, Other Matters." in the Notes to Consolidated Financial Statements.
• During the second quarter of 2018, we executed a tender offer for $209.0 million of outstanding notes consisting of a
combination of our 6.80% notes due 2019, 5.45% notes due 2020 and 6.125% notes due 2022. During the third quarter of
2018, we redeemed $551.1 million of outstanding notes representing the remainder of our 6.80% notes due 2019, 5.45% notes
due 2020 and 6.125% notes due 2022. In conjunction with our debt retired, we recorded a $45.5 million loss on early
extinguishment of long-term debt primarily attributable to early redemption premiums.
25
Table of Contents
ITEM 6. SELECTED FINANCIAL DATA
NISOURCE INC.
• The decrease in net income during 2017 was due primarily to increased tax expense as a result of the impact of adopting the
provisions of the TCJA and a loss on early extinguishment of long-term debt, as discussed below.
• During the second quarter of 2017, we executed a tender offer for $990.7 million of outstanding notes consisting of a
combination of our 6.40% notes due 2018, 6.80% notes due 2019, 5.45% notes due 2020, and 6.125% notes due 2022. In
conjunction with the debt retired, we recorded a $111.5 million loss on early extinguishment of long-term debt, primarily
attributable to early redemption premiums.
•
Prior to the Separation, CPG closed the placement of $2,750.0 million in aggregate principal amount of senior notes. Using
the proceeds from this offering, CPG made cash payments to us representing the settlement of inter-company borrowings
and the payment of a one-time special dividend. In May 2015, using proceeds from the cash payments from CPG, we settled
two bank term loans in the amount of $1,075.0 million and executed a tender offer for $750.0 million consisting of a
combination of its 5.25% notes due 2017, 6.40% notes due 2018 and 4.45% notes due 2021. In conjunction with the debt
retired, we recorded a $97.2 million loss on early extinguishment of long-term debt, primarily attributable to early redemption
premiums.
26
Table of Contents
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS
NISOURCE INC.
Index
Executive Summary .............................................................................................................................................................
Summary of Consolidated Financial Results ..................................................................................................................
Results and Discussion of Segment Operations ...................................................................................................................
Gas Distribution Operations ............................................................................................................................................
Electric Operations ..........................................................................................................................................................
Liquidity and Capital Resources ..........................................................................................................................................
Off Balance Sheet Arrangements .........................................................................................................................................
Market Risk Disclosures ......................................................................................................................................................
Other Information.................................................................................................................................................................
Page
27
29
31
32
36
40
44
44
45
EXECUTIVE SUMMARY
This Management’s Discussion and Analysis of Financial Condition and Results of Operations (Management’s Discussion) analyzes
our financial condition, results of operations and cash flows and those of our subsidiaries. It also includes management’s analysis
of past financial results and certain potential factors that may affect future results, potential future risks and approaches that may
be used to manage those risks. See "Note regarding forward-looking statements" at the beginning of this report for a list of factors
that may cause results to differ materially.
Management’s Discussion is designed to provide an understanding of our operations and financial performance and should be read
in conjunction with our Consolidated Financial Statements and related Notes to Consolidated Financial Statements in this annual
report.
We are an energy holding company under the Public Utility Holding Company Act of 2005 whose subsidiaries are fully regulated
natural gas and electric utility companies serving customers in seven states. We generate substantially all of our operating income
through these rate-regulated businesses which are summarized for financial reporting purposes into two primary reportable
segments: Gas Distribution Operations and Electric Operations.
Refer to the “Business” section under Item 1 of this annual report and Note 23, "Segments of Business," in the Notes to Consolidated
Financial Statements for further discussion of our regulated utility business segments.
Our goal is to develop strategies that benefit all stakeholders as we address changing customer conservation patterns, develops
more contemporary pricing structures and embarks on long-term infrastructure investment and safety programs. These strategies
are intended to improve reliability and safety, enhance customer services and reduce emissions while generating sustainable returns.
Additionally, we continue to pursue regulatory and legislative initiatives that will allow residential customers not currently on our
system to obtain gas service in a cost effective manner. Refer also to the discussion of Electric Supply within our Electric Operations
Segment discussion for additional information on our long term electric generation strategy.
Greater Lawrence Incident: The Greater Lawrence Incident occurred on September 13, 2018. The following table summarizes
expenses incurred and insurance recoveries recorded since the Greater Lawrence Incident. The amounts set forth in the table below
do not include the capital cost of the pipeline replacement described below and as set forth in Note 19, "Other Commitments and
Contingencies - E. Other Matters - Greater Lawrence Pipeline Replacement," in the Notes to Consolidated Financial Statements.
(in millions)
Third-party claims and government fines, penalties and settlements
Other incident-related costs
Total
Insurance recoveries recorded
Loss (benefit) to income before income taxes
Year Ended
Year Ended
December 31,
2018
December 31,
2019
Incident to
Date
$
$
757
266
1,023
(135)
888
$
$
284 $
154
438
(665)
(227) $
1,041
420
1,461
(800)
661
Inclusive of the $1,041 million of third-party claims and fines, penalties and settlements associated with government investigations
recorded incident to date, we estimate that total costs related to third-party claims and fines, penalties and settlements associated
27
Table of Contents
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS (continued)
NISOURCE INC.
with government investigations as set forth in Note 19, "Other Commitments and Contingencies - C. Legal Proceedings," will
range from $1,041 million to $1,065 million, depending on the number, nature, final outcome and value of third-party claims and
the final outcome of government investigations. These costs do not include costs of certain third-party claims and fines, penalties
or settlements with government investigations that we are not able to estimate. We expect to incur a total of $450 million to $460
million in other incident-related costs, inclusive of the $420 million recorded incident to date, as set forth in Note 19, "Other
Commitments and Contingencies - E. Other Matters - Greater Lawrence Incident Restoration."
The process for estimating costs associated with third-party claims and fines, penalties and settlements associated with government
investigations relating to the Greater Lawrence Incident requires management to exercise significant judgment based on a number
of assumptions and subjective factors. As more information becomes known, including additional information regarding ongoing
investigations, management’s estimates and assumptions regarding the financial impact of the Greater Lawrence Incident may
change.
The aggregate amount of third-party liability insurance coverage available for losses arising from the Greater Lawrence Incident
is $800 million. We have collected the entire $800 million as of December 31, 2019. Expenses related to the incident have exceeded
the total amount of insurance coverage available under our policies. The following table presents activity related to our Greater
Lawrence Incident insurance recovery.
(in millions)
Balance, December 31, 2018
Insurance recoveries recorded in first quarter of 2019
Cash collected from insurance recoveries in the first quarter of 2019
Balance, March 31, 2019
Insurance recoveries recorded in the second quarter of 2019
Cash collected from insurance recoveries in the second quarter of 2019
Balance, June 30, 2019
Insurance recoveries recorded in third quarter of 2019
Cash collected from insurance recoveries in the third quarter of 2019
Balance, September 30, 2019
Insurance recoveries recorded in the fourth quarter of 2019
Cash collected from insurance recoveries in the fourth quarter of 2019
Balance, December 31, 2019
(1)$5 million of insurance recoveries were collected during 2018.
Insurance
receivable(1)
130
$
100
(108)
122
435
(297)
260
—
(260)
—
130
(130)
—
$
$
$
Since the Greater Lawrence Incident and through December 31, 2019, we have invested approximately $258 million of capital
spend for the pipeline replacement; this work was completed in 2019. We maintain property insurance for gas pipelines and other
applicable property. Columbia of Massachusetts has filed a proof of loss with its property insurer for the full cost of the pipeline
replacement. In January 2020, we filed a lawsuit against the property insurer, seeking payment of our property claim. We are
currently unable to predict the timing or amount of any insurance recovery under the property policy. The recovery of any capital
investment not reimbursed through insurance will be addressed in a future regulatory proceeding; a future regulatory proceeding
is dependent on the outcome of the sale of the Massachusetts Business. The outcome of such a proceeding (if any) is uncertain.
In accordance with ASC 980-360, if it becomes probable that a portion of the pipeline replacement cost will not be recoverable
through customer rates and an amount can be reasonably estimated, we will reduce our regulated plant balance for the amount of
the probable disallowance and record an associated charge to earnings. This could result in a material adverse effect on our financial
condition, results of operations and cash flows. Additionally, if a rate order is received allowing recovery of the investment with
no or reduced return on investment, a loss on disallowance may be required.
Refer to Note 19, "Other Commitments and Contingencies - C. Legal Proceedings" and " - E. Other Matters," in the Notes to
Consolidated Financial Statements, "Summary of Consolidated Financial Results," "Results and Discussion of Segment Operation
- Gas Distribution Operations," and "Liquidity and Capital Resources" in this Management's Discussion for additional information
related to the Greater Lawrence Incident.
28
Table of Contents
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS (continued)
NISOURCE INC.
Additionally, as discussed in Note 6, "Goodwill and Other Intangible Assets," in the Notes to Consolidated Financial Statements,
we assessed the totality of several factors that developed during the fourth quarter related to the Greater Lawrence Incident and
concluded that it was more likely than not that the fair value of the Columbia of Massachusetts reporting unit was below its carrying
value. As a result, a new impairment analysis was required for our Columbia of Massachusetts reporting unit. The year-end
impairment analysis indicated that the fair value of the Columbia of Massachusetts reporting unit was below its carrying value.
As a result, we reduced the Columbia of Massachusetts reporting unit goodwill balance to zero and recognized a goodwill impairment
charge totaling $204.8 million, which is non-deductible for tax purposes. We assessed the same fourth quarter circumstances in
reviewing the Columbia of Massachusetts franchise rights intangible assets. These factors led us to conclude that it was more
likely than not that the fair value of the franchise rights was below its carrying amount. As a result, we performed a year-end
impairment test and determined that the fair value of the franchise rights was zero. Therefore, we wrote off the entire franchise
rights book value, which resulted in an impairment charge totaling $209.7 million.
Columbia of Massachusetts Asset Sale: On February 26, 2020, NiSource and Columbia of Massachusetts entered into the Asset
Purchase Agreement with Eversource. Upon the terms and subject to the conditions set forth in the Asset Purchase Agreement,
NiSource and Columbia of Massachusetts agreed to sell to Eversource the Massachusetts Business for a purchase price of $1,100
million, subject to adjustment. For additional information, see Note 26, “Subsequent Event,” in the Notes to Consolidated Financial
Statements.
Summary of Consolidated Financial Results
Our operations are affected by the cost of sales. Cost of sales for the Gas Distribution Operations segment is principally comprised
of the cost of natural gas used while providing transportation and distribution services to customers. Cost of sales for the Electric
Operations segment is comprised of the cost of coal, related handling costs, natural gas purchased for the internal generation of
electricity at NIPSCO and the cost of power purchased from third-party generators of electricity.
The majority of the cost of sales are tracked costs that are passed through directly to the customer resulting in an equal and offsetting
amount reflected in operating revenues. As a result, we believe net revenues, a non-GAAP financial measure defined as operating
revenues less cost of sales (excluding depreciation and amortization), provides management and investors a useful measure to
analyze profitability. The presentation of net revenues herein is intended to provide supplemental information for investors regarding
operating performance. Net revenues do not intend to represent operating income, the most comparable GAAP measure, as an
indicator of operating performance and is not necessarily comparable to similarly titled measures reported by other companies.
29
Table of Contents
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS (continued)
NISOURCE INC.
For the years ended December 31, 2019, 2018 and 2017, operating income and a reconciliation of net revenues to the most directly
comparable GAAP measure, operating income, was as follows:
Year Ended December 31, (in millions)
Operating Income
2019
2018
2017
2019 vs. 2018
2018 vs. 2017
$
890.7
$
124.7
$
921.2
$
766.0
$
(796.5)
2019
2018
2017
2019 vs. 2018
2018 vs. 2017
Year Ended December 31, (in millions, except per share
amounts)
Operating Revenues
Cost of sales (excluding depreciation and amortization)
Total Net Revenues
Other Operating Expenses
Operating Income
Total Other Deductions, Net
Income Taxes
Net Income (Loss)
Preferred dividends
Net Income (Loss) Available to Common Shareholders
$
5,208.9
$
5,114.5
$
4,874.6
$
94.4
$
1,534.8
3,674.1
2,783.4
890.7
(384.1)
123.5
383.1
(55.1)
328.0
1,761.3
3,353.2
3,228.5
124.7
(355.3)
(180.0)
(50.6)
(15.0)
(65.6)
1,518.7
3,355.9
2,434.7
921.2
(478.2)
314.5
128.5
—
128.5
(226.5)
320.9
(445.1)
766.0
(28.8)
303.5
433.7
(40.1)
393.6
Basic Earnings (Loss) Per Share
Basic Average Common Shares Outstanding
$
0.88
$
(0.18) $
0.39
$
1.06
$
374.6
356.5
329.4
18.1
239.9
242.6
(2.7)
793.8
(796.5)
122.9
(494.5)
(179.1)
(15.0)
(194.1)
(0.57)
27.1
On a consolidated basis, we reported net income available to common shareholders of $328.0 million or $0.88 per basic share for
the twelve months ended December 31, 2019 compared to a loss to common shareholders of $65.6 million or $0.18 per basic share
for the same period in 2018. The increase in net income available to common shareholders during 2019 was primarily due to lower
operating expenses related to the Greater Lawrence Incident, insurance recoveries recorded related to the Greater Lawrence Incident,
and new rates from base rate proceedings and infrastructure replacement programs. These increases were partially offset by non-
cash impairments of goodwill and other intangible assets in 2019 related to Columbia of Massachusetts (see Note 6, "Goodwill
and Other Intangible Assets," in the Notes to Consolidated Financial Statements for additional information), higher income taxes
(see "Income Taxes" below), higher depreciation expense due to regulatory outcomes at NIPSCO and Columbia of Ohio, and
additional dilution in 2019 resulting from preferred stock dividend commitments.
Operating Income
For the twelve months ended December 31, 2019, we reported operating income of $890.7 million compared to $124.7 million
for the same period in 2018. The increased operating income was primarily due to decreased operating expenses related to the
Greater Lawrence Incident, insurance recoveries recorded related to the Greater Lawrence Incident, and new rates from base rate
proceedings and infrastructure replacement programs. These increases were partially offset by non-cash impairments of goodwill
and other intangible assets in 2019 related to Columbia of Massachusetts (see Note 6, "Goodwill and Other Intangible Asset," in
the Notes to Consolidated Financial Statements for additional information), and increased depreciation due to the regulatory
outcome of NIPSCO's gas rate case and an increase in amortization of depreciation previously deferred as a regulatory asset
resulting from Columbia of Ohio's CEP.
Other Deductions, Net
Other deductions, net reduced income by $384.1 million in 2019 compared to a reduction in income of $355.3 million in 2018.
This change is primarily due to lower actuarial investment returns on pension and other postretirement benefit assets of $34.6
million, and an increase in interest expense of $25.6 million driven by decreased regulatory deferrals from Columbia of Ohio's
CEP. These unfavorable variances were partially offset by charitable contributions of $20.7 million in 2018 related to the Greater
Lawrence Incident.
Income Taxes
The increase in income tax expense from 2018 to 2019 is primarily attributable to higher pre-tax income resulting from the items
discussed above in "Operating Income" and "Other Deductions, Net," true-ups to tax expense in 2018 to reflect regulatory outcomes
associated with excess deferred income taxes, and higher income tax expense in 2019 related to the non-deductible, non-cash
impairment of goodwill, fines and penalties.
30
Table of Contents
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS (continued)
NISOURCE INC.
Refer to “Liquidity and Capital Resources” below and Note 10, "Income Taxes," in the Notes to Consolidated Financial Statements
for additional information on income taxes and the change in the effective tax rate.
Capital Investment
In 2019, we invested approximately $1.9 billion in capital expenditures across the gas and electric utilities. These expenditures
were primarily aimed at furthering the safety and reliability of our gas distribution system, and maintaining our existing electric
generation fleet.
We continue to execute on an estimated $30 billion in total projected long-term regulated utility infrastructure investments and
expect to invest approximately $1.8 to $1.9 billion in capital during 2020 as we continue to focus on growth, safety and modernization
projects across our operating area.
Liquidity
A primary focus of ours is to ensure the availability of adequate financing to fund our ongoing safety and infrastructure investment
programs which typically involves the issuance of debt and/or equity. In addition, expenses related to the Greater Lawrence Incident
have exceeded the total amount of insurance coverage available under our policies. During 2020, we plan to pursue alternatives
to cover this shortfall, including long-term financing and potential proceeds from the sale of the Massachusetts Business. For
additional information, see Note 26, "Subsequent Event," in the Notes to Consolidated Financial Statements.
Through income generated from operating activities, amounts available under our short-term revolving credit facility, commercial
paper program, accounts receivable securitization facilities, term loan borrowings, long-term debt agreements, our ability to access
the capital markets and the potential sale of the Massachusetts Business, we believe there is adequate capital available to fund our
operating activities and capital expenditures and the effects of the Greater Lawrence Incident in 2020 and beyond. At December 31,
2019 and 2018, we had approximately $1,409.1 million and $974.6 million, respectively, of net liquidity available, consisting of
cash and available capacity under credit facilities.
These factors and other impacts to the financial results are discussed in more detail within the following discussions of “Results
and Discussion of Segment Operations” and “Liquidity and Capital Resources.”
Regulatory Developments
In 2019, we continued to move forward on core infrastructure and environmental investment programs supported by complementary
regulatory and customer initiatives across all seven states of our operating area. Refer to Note 8, “Regulatory Matters” and Note
19-E, "Other Matters," in the Notes to Consolidated Financial Statements for a complete discussion of key regulatory developments
that transpired during 2019.
RESULTS AND DISCUSSION OF SEGMENT OPERATIONS
Presentation of Segment Information
Our operations are divided into two primary reportable segments: Gas Distribution Operations and Electric Operations.
31
Table of Contents
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS (continued)
NISOURCE INC.
Gas Distribution Operations
For the years ended December 31, 2019, 2018 and 2017, operating income (loss) and a reconciliation of net revenues to the
most directly comparable GAAP measure, operating income (loss), was as follows:
Year Ended December 31, (in millions)
Operating Income (Loss)
2019
2018
2017
2019 vs. 2018
2018 vs. 2017
$
675.4
$ (254.1)
$
550.1
$
929.5
$
(804.2)
Year Ended December 31, (in millions)
Net Revenues
Operating revenues
Less: Cost of sales (excluding depreciation and
amortization)
Net Revenues
Operating Expenses
Operation and maintenance
Depreciation and amortization
Impairment of other intangible assets
Loss on sale of fixed assets and impairments, net
Other taxes
Total Operating Expenses
Operating Income (Loss)
Revenues
Residential
Commercial
Industrial
Off-System
Other
Total
Sales and Transportation (MMDth)
Residential
Commercial
Industrial
Off-System
Other
Total
Heating Degree Days
Normal Heating Degree Days
% Warmer than Normal
Gas Distribution Customers
Residential
Commercial
Industrial
Other
Total
2019
2018
2017
2019 vs. 2018
2018 vs. 2017
$ 3,522.8
$ 3,419.5
$ 3,102.1
$
103.3
$
317.4
1,067.6
2,455.2
935.7
403.2
209.7
0.1
231.1
1,779.8
1,259.3
2,160.2
1,908.1
301.0
—
0.2
205.0
2,414.3
1,005.0
2,097.1
1,090.8
269.3
—
2.8
184.1
1,547.0
$
$
$
675.4
$
(254.1)
$
550.1
$ 2,317.2
$ 2,248.3
$ 2,029.4
775.1
245.8
77.7
107.0
753.7
228.6
92.4
96.5
669.4
217.5
111.8
74.0
(191.7)
295.0
(972.4)
102.2
209.7
(0.1)
26.1
(634.5)
929.5
68.9
21.4
17.2
(14.7)
10.5
$
$
$ 3,522.8
$ 3,419.5
$ 3,102.1
$
103.3
$
274.9
189.6
542.5
32.9
0.3
280.3
187.6
555.7
30.0
—
1,040.2
1,053.6
5,375
5,452
5,562
5,610
247.1
169.3
517.5
39.0
0.3
973.2
4,927
5,610
(1)%
(1)%
(12)%
3,221,178
3,194,662
3,168,516
282,778
5,982
3
281,517
280,362
5,833
3
6,228
4
(5.4)
2.0
(13.2)
2.9
0.3
(13.4)
(187)
(158)
26,516
1,261
149
—
254.3
63.1
817.3
31.7
—
(2.6)
20.9
867.3
(804.2)
218.9
84.3
11.1
(19.4)
22.5
317.4
33.2
18.3
38.2
(9.0)
(0.3)
80.4
635
—
26,146
1,155
(395)
(1)
3,509,941
3,482,015
3,455,110
27,926
26,905
32
Table of Contents
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS (continued)
NISOURCE INC.
Gas Distribution Operations (continued)
Comparability of line item operating results may be impacted by regulatory, tax and depreciation trackers (other than those for
cost of sales) that allow for the recovery in rates of certain costs. Therefore, increases in these tracked operating expenses are
generally offset by increases in net revenues and have essentially no impact on net income.
2019 vs. 2018 Operating Income
For 2019, Gas Distribution Operations reported operating income of $675.4 million, an increase in income of $929.5 million from
the comparable 2018 period.
Net revenues for 2019 were $2,455.2 million, an increase of $295.0 million from the same period in 2018. The change in net
revenues was primarily driven by:
• New rates from base rate proceedings and infrastructure replacement programs of $243.2 million.
• Higher regulatory, depreciation, and tax trackers, which are offset in operating expense, of $36.2 million.
• Higher revenues of $14.5 million resulting from an update in the weather-related normal heating degree day methodology
(see further detail below), partially offset by a $7.1 million revenue decrease from the effects of warmer weather in 2019.
• The effects of commercial and residential customer growth of $12.8 million.
Operating expenses were $634.5 million lower in 2019 compared to 2018. This change was primarily driven by:
• Decreased expenses related to third-party claims and other costs for the Greater Lawrence Incident of $1,090.7 million,
net of insurance recoveries recorded.
Partially offset by:
• Non-cash impairment of the Columbia of Massachusetts franchise rights of $209.7 million.
•
Increased depreciation of $103.8 million due to the regulatory outcome of NIPSCO's gas rate case, an increase in
amortization of depreciation previously deferred as a regulatory asset resulting from Columbia of Ohio's CEP, and higher
capital expenditures placed in service.
• Higher employee and administrative expenses of $50.2 million driven by resources shifting from the temporary assistance
on the Greater Lawrence Incident restoration to normal operations (offset in the decreased Greater Lawrence Incident
costs discussed above) and an increase in headcount.
Increased regulatory, depreciation, and tax trackers, which are offset in net revenues, of $36.2 million.
•
• Higher property taxes of $22.2 million primarily due to increased amortization of property taxes previously deferred as
a regulatory asset resulting from Columbia of Ohio's CEP, as well as higher capital expenditures placed in service.
• Higher outside services of $17.4 million primarily due to increased line location and safety-related work.
• Higher insurance expense of $9.1 million primarily driven by increased premiums.
2018 vs. 2017 Operating Income
For 2018, Gas Distribution Operations reported an operating loss of $254.1 million, a decrease in income of $804.2 million from
the comparable 2017 period.
Net revenues for 2018 were $2,160.2 million, an increase of $63.1 million from the same period in 2017. The change in net revenues
was primarily driven by:
• New rates from infrastructure replacement programs and base rate proceedings of $99.6 million.
• Higher revenues from the effects of colder weather in 2018 of $37.5 million.
• The effects of customer growth and increased usage of $17.4 million.
• Higher regulatory, tax and depreciation trackers, which are offset in operating expense, of $16.0 million.
Partially offset by:
• A revenue reserve of $85.0 million in 2018 resulting from the probable future refund of certain collections from customers
as a result of the lower income tax rate from the TCJA.
• Decreased rates from implementation of regulatory outcomes related to the TCJA of $24.7 million.
33
Table of Contents
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS (continued)
NISOURCE INC.
Gas Distribution Operations (continued)
Operating expenses were $867.3 million higher in 2018 compared to 2017. This change was primarily driven by:
• Expenses related to third-party claims and other costs for the Greater Lawrence Incident of $864.4 million, net of insurance
•
recoveries recorded.
Increased depreciation of $29.6 million due to regulatory outcomes of NIPSCO's gas rate case and higher capital
expenditures placed in service.
• Higher regulatory, tax and depreciation trackers, which are offset in net revenues, of $16.0 million.
•
Increased property taxes of $11.0 million due to higher capital expenditures placed in service and the impact of regulatory-
driven property tax deferrals.
Partially offset by:
• Decreased outside services of $33.2 million primarily due to IT service provider transition and other strategic initiative
costs in 2017, lower ongoing IT costs and a temporary shift of resources to the Greater Lawrence Incident restoration.
• Lower employee and administrative expenses of $30.2 million driven by reduced incentive compensation and a temporary
shift of resources to the Greater Lawrence Incident restoration.
Weather
In general, we calculate the weather-related revenue variance based on changing customer demand driven by weather variance
from normal heating degree days. Our composite heating degree days reported do not directly correlate to the weather-related
dollar impact on the results of Gas Distribution Operations. Heating degree days experienced during different times of the year or
in different operating locations may have more or less impact on volume and dollars depending on when and where they occur.
When the detailed results are combined for reporting, there may be weather-related dollar impacts on operations when there is not
an apparent or significant change in our aggregated composite heating degree day comparison.
The definition of “normal” weather was updated during the first quarter of 2019 to reflect more current weather pattern data and
to more closely align with the regulators' jurisdictional definitions of “normal” weather. Impacts of the change in methodology
will be reflected prospectively and disclosed to the extent it results in notable year-over-year variances in net revenues.
Weather in the Gas Distribution Operations service territories for 2019 was about 1% warmer than normal and about 3% warmer
than 2018; however, due to the aforementioned change in methodology, the change in net revenues attributed to weather resulted
in an increase of $7.4 million for the year ended December 31, 2019 compared to 2018. The variance is detailed further below:
• An update in the weather-related normal heating degree day methodology resulting in a favorable variance attributed to
weather of $14.5 million, as discussed above.
Offset by:
• The effects of warmer weather in 2019 of $7.1 million.
Weather in the Gas Distribution Operations service territories for 2018 was about 1% warmer than normal and about 13% colder
than 2017, increasing net revenues $37.5 million for the year ended December 31, 2018 compared to 2017.
Throughput
Total volumes sold and transported for the year ended December 31, 2019 were 1,040.2 MMDth, compared to 1,053.6 MMDth
for 2018. This decrease is primarily attributable to warmer weather experienced in 2019 compared to 2018.
Total volumes sold and transported for the year ended December 31, 2018 were 1,053.6 MMDth, compared to 973.2 MMDth for
2017. This increase is primarily attributable to colder weather experienced in 2018 compared to 2017.
Economic Conditions
All of our Gas Distribution Operations companies have state-approved recovery mechanisms that provide a means for full recovery
of prudently incurred gas costs. Gas costs are treated as pass-through costs and have no impact on the net revenues recorded in
the period. The gas costs included in revenues are matched with the gas cost expense recorded in the period and the difference is
recorded on the Consolidated Balance Sheets as under-recovered or over-recovered gas cost to be included in future customer
billings.
34
Table of Contents
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS (continued)
NISOURCE INC.
Gas Distribution Operations (continued)
Certain Gas Distribution Operations companies continue to offer choice opportunities, where customers can choose to purchase
gas from a third-party supplier, through regulatory initiatives in their respective jurisdictions. These programs serve to further
reduce our exposure to gas prices.
Greater Lawrence Incident
Refer to Note 19-C. "Legal Proceedings," and E. "Other Matters," in the Notes to Consolidated Financial Statements, "Summary
of Consolidated Financial Results" and "Liquidity and Capital Resources" in this Management's Discussion, and Part I. Item 1A.
"Risk Factors" for additional information related to the Greater Lawrence Incident.
Columbia of Massachusetts Asset Sale
On February 26, 2020, we entered into the Asset Purchase Agreement with Eversource providing for the sale of the Massachusetts
Business to Eversource, subject to the terms and conditions set forth in the agreement. For additional information, see Note 26,
“Subsequent Event,” in the Notes to Consolidated Financial Statements.
35
Table of Contents
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS (continued)
NISOURCE INC.
Electric Operations
For the years ended December 31, 2019, 2018 and 2017, operating income and a reconciliation of net revenues to the most
directly comparable GAAP measure, operating income, was as follows:
Year Ended December 31, (in millions)
Operating Income
2019
2018
2017
2019 vs. 2018
2018 vs. 2017
$
406.8
$
386.1
$
367.4
$
20.7
$
18.7
Year Ended December 31, (in millions)
2019
2018
2017
2019 vs. 2018
2018 vs. 2017
Net Revenues
Operating revenues
Less: Cost of sales (excluding depreciation and
amortization)
Net Revenues
Operating Expenses
Operation and maintenance
Depreciation and amortization
Loss (gain) on sale of fixed assets and impairments, net
Other taxes
Total Operating Expenses
Operating Income
Revenues
Residential
Commercial
Industrial
Wholesale
Other
Total
Sales (Gigawatt Hours)
Residential
Commercial
Industrial
Wholesale
Other
Total
Cooling Degree Days
Normal Cooling Degree Days
% Warmer than Normal
Electric Customers
Residential
Commercial
Industrial
Wholesale
Other
Total
$
1,699.2
$
1,708.2
$
1,786.5
$
(9.0)
$
(78.3)
467.3
1,231.9
502.1
1,206.1
513.9
1,272.6
495.0
277.3
(0.1)
52.9
825.1
406.8
481.6
486.7
608.4
11.7
110.8
$
$
500.0
262.9
—
57.1
820.0
386.1
494.7
492.6
614.4
15.7
90.8
$
$
565.6
277.8
1.9
59.9
905.2
367.4
476.9
501.2
698.1
11.6
98.7
$
$
$
$
(34.8)
25.8
(5.0)
14.4
(0.1)
(4.2)
5.1
20.7
(13.1)
(5.9)
(6.0)
(4.0)
20.0
$
$
(11.8)
(66.5)
(65.6)
(14.9)
(1.9)
(2.8)
(85.2)
18.7
17.8
(8.6)
(83.7)
4.1
(7.9)
$
1,699.2
$
1,708.2
$
1,786.5
$
(9.0)
$
(78.3)
3,369.5
3,760.3
8,466.1
8.2
117.2
3,535.2
3,844.6
8,829.5
114.3
124.4
3,301.7
3,793.5
9,469.7
32.5
128.2
15,721.3
16,448.0
16,725.6
962
803
1,180
806
20%
46%
837
806
4%
(165.7)
(84.3)
(363.4)
(106.1)
(7.2)
(726.7)
(218)
(3)
233.5
51.1
(640.2)
81.8
(3.8)
(277.6)
343
—
415,534
412,267
409,401
3,267
2,866
57,058
2,256
726
2
56,605
2,284
735
2
56,134
2,305
739
2
453
(28)
(9)
—
471
(21)
(4)
—
475,576
471,893
468,581
3,683
3,312
36
Table of Contents
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS (continued)
NISOURCE INC.
Electric Operations (continued)
Comparability of line item operating results may be impacted by regulatory and depreciation trackers (other than those for cost
of sales) that allow for the recovery in rates of certain costs. Therefore, increases in these tracked operating expenses are offset
by increases in net revenues and have essentially no impact on net income.
2019 vs. 2018 Operating Income
For 2019, Electric Operations reported operating income of $406.8 million, an increase of $20.7 million from the comparable
2018 period.
Net revenues for 2019 were $1,231.9 million, an increase of $25.8 million from the same period in 2018. The change in net
revenues was primarily driven by:
• New rates from the recent rate case proceeding, incremental capital spend on infrastructure replacement programs, and
electric transmission projects of $24.8 million.
• Decreased fuel handling costs of $11.0 million.
• Higher regulatory and depreciation trackers, which are offset in operating expense, of $8.4 million.
•
Increased commercial and residential customer growth of $3.9 million.
Partially offset by:
• Lower revenues from the effects of cooler weather of $15.1 million.
• Decreased residential, commercial and industrial usage of $10.8 million.
Operating expenses were $5.1 million higher in 2019 than 2018. This change was primarily driven by:
• Higher regulatory and depreciation trackers, which are offset in net revenues, of $8.4 million.
Increased depreciation of $8.7 million due to higher capital expenditures placed in service.
•
Partially offset by:
• Decreased materials and supplies costs of $7.8 million, primarily related to the retirement of Bailly Generating Station
Units 7 and 8 on May 31, 2018.
• Decreased employee and administrative costs of $5.0 million.
2018 vs. 2017 Operating Income
For 2018, Electric Operations reported operating income of $386.1 million, an increase of $18.7 million from the comparable
2017 period.
Net revenues for 2018 were $1,206.1 million, a decrease of $66.5 million from the same period in 2017. The change in net revenues
was primarily driven by:
• Lower regulatory and depreciation trackers, which are offset in operating expense, of $35.6 million.
• Decreased rates from implementation of regulatory outcomes related to the TCJA of $32.9 million.
• Decreased industrial usage of $17.1 million.
• A revenue reserve of $16.2 million in 2018 resulting from the probable future refund of certain collections from customers
as a result of the lower income tax rate from the TCJA .
Increased fuel handling costs of $7.3 million.
•
Partially offset by:
• The effects of warmer weather of $25.2 million.
•
Increased rates from infrastructure replacement programs of $18.6 million.
Operating expenses were $85.2 million lower in 2018 than 2017. This change was primarily driven by:
• Lower regulatory and depreciation trackers, which are offset in net revenues, of $35.6 million.
• Lower outside service costs of $32.1 million and lower material and supplies costs of $10.2 million primarily related to
the retirement of Bailly Generating Station Units 7 and 8 on May 31, 2018.
• Decreased employee and administrative costs of $18.4 million.
37
Table of Contents
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS (continued)
NISOURCE INC.
Electric Operations (continued)
Partially offset by:
•
Increased depreciation of $10.0 million due to higher capital expenditures placed in service.
Weather
In general, we calculate the weather-related revenue variance based on changing customer demand driven by weather variance
from normal heating or cooling degree days. Our composite heating or cooling degree days reported do not directly correlate to
the weather-related dollar impact on the results of Electric Operations. Heating or cooling degree days experienced during different
times of the year may have more or less impact on volume and dollars depending on when they occur. When the detailed results
are combined for reporting, there may be weather-related dollar impacts on operations when there is not an apparent or significant
change in our aggregated composite heating or cooling degree day comparison.
The definition of “normal” weather was updated during the first quarter of 2019 to reflect more current weather pattern data and
to more closely align with the regulators' jurisdictional definitions of “normal” weather. Impacts of the change in methodology
will be reflected prospectively and disclosed to the extent it results in notable year-over-year variances in net revenues.
Weather in the Electric Operations’ territories for 2019 was 20% warmer than normal and 18% cooler than the same period in
2018, decreasing net revenues $15.1 million for the year ended December 31, 2019 compared to 2018.
Weather in the Electric Operations’ territories for 2018 was 46% warmer than normal and 41% warmer than the same period in
2017, increasing net revenues $25.2 million for the year ended December 31, 2018 compared to 2017.
Sales
Electric Operations sales were 15,721.3 GWh for 2019, a decrease of 726.7 GWh, or 4.4% compared to 2018. This decrease was
primarily attributable to higher internal generation from large industrial customers in 2019 and the effects of cooler weather on
residential and commercial customers.
Electric Operations sales were 16,448.0 GWh for 2018, a decrease of 277.6 GWh, or 1.7% compared to 2017. This decrease
was primarily attributable to higher internal generation from large industrial customers in 2018, partially offset by increased
volumes for residential and commercial customers resulting from warmer weather.
BP Products North America. On March 29, 2018, WCE, which is currently owned by BP p.l.c ("BP") and BP Products North
America, which operates the BP Refinery, filed a petition at the IURC asking that the combined operations of WCE and BP be
treated as a single premise, and the WCE generation be dedicated primarily to BP Refinery operations beginning in May 2019 as
WCE has self-certified as a qualifying facility at FERC. BP Refinery planned to continue to purchase electric service from NIPSCO
at a reduced demand level beginning May 2019; however, a settlement agreement was filed on November 2, 2018 agreeing that
BP and WCE would not move forward with construction of a private transmission line to serve BP until conclusion of NIPSCO's
pending electric rate case. The IURC approved the settlement agreement as filed on February 20, 2019. On December 4, 2019,
the IURC issued an order in the electric rate case approving the implementation of a new industrial service structure. This resolved
the issues included in BP’s original petition. Refer to Note 8, "Regulatory Matters," in the Notes to Consolidated Financial
Statements for additional information.
Economic Conditions
NIPSCO has a state-approved recovery mechanism that provides a means for full recovery of prudently incurred fuel costs. Fuel
costs are treated as pass-through costs and have no impact on the net revenues recorded in the period. The fuel costs included in
revenues are matched with the fuel cost expense recorded in the period and the difference is recorded on the Consolidated Balance
Sheets as under-recovered or over-recovered fuel cost to be included in future customer billings.
NIPSCO's performance remains closely linked to the performance of the steel industry. NIPSCO’s MWh sales to steel-related
industries accounted for approximately 51.5% and 49.7% of the total industrial MWh sales for the years ended December 31,
2019 and 2018, respectively.
Electric Supply
NIPSCO 2018 Integrated Resource Plan. Multiple factors, but primarily economic ones, including low natural gas prices, advancing
cost effective renewable technology and increasing capital and operating costs associated with existing coal plants, have led
NIPSCO to conclude in its October 2018 Integrated Resource Plan submission that NIPSCO’s current fleet of coal generation
facilities will be retired earlier than previous Integrated Resource Plan’s had indicated.
38
Table of Contents
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS (continued)
NISOURCE INC.
Electric Operations (continued)
The Integrated Resource Plan evaluated demand-side and supply-side resource alternatives to reliably and cost effectively meet
NIPSCO customers' future energy requirements over the ensuing 20 years. The preferred option within the Integrated Resource
Plan retires R.M. Schahfer Generating Station (Units 14, 15, 17, and 18) by 2023 and Michigan City Generating Station (Unit 12)
by 2028. These units represent 2,080 MW of generating capacity, equal to 72% of NIPSCO’s remaining capacity after the retirement
of Bailly Units 7 and 8 in May of 2018.
The current replacement plan includes renewable sources of energy, including wind, solar, and battery storage to be obtained
through a combination of NIPSCO ownership and PPAs. Refer to Note 19-E, "Other Matters," in the Notes to Consolidated
Financial Statements for further discussion.
39
Table of Contents
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS (continued)
NISOURCE INC.
Liquidity and Capital Resources
Greater Lawrence Incident: As discussed in the "Executive Summary" and in Note 19, “Other Commitments and Contingencies”
in the Notes to Consolidated Financial Statements, we have recorded and paid costs associated with the Greater Lawrence Incident
and have invested capital to replace the entire affected 45-mile cast iron and bare steel pipeline system that delivers gas to the
impacted area. As discussed in the "Executive Summary," Note 19 referenced earlier in this paragraph, and Part I, Item 1A “Risk
Factors,” we may incur additional expenses and liabilities in excess of our recorded liabilities and estimated additional costs
associated with the Greater Lawrence Incident. Since the Greater Lawrence Incident and through December 31, 2019, we have
collected $800 million from insurance providers; however, total costs related to the incident have exceeded the total amount of
insurance coverage available under our policies. To date, this excess has primarily been funded through short-term borrowings.
During 2020, we plan to pursue alternatives to these short-term borrowings, which include long-term financing and potential
proceeds from the sale of the Massachusetts Business. For additional information, see Note 26, “Subsequent Event,” in the Notes
to Consolidated Financial Statements.
Operating Activities
Net cash from operating activities for the year ended December 31, 2019 was $1,583.3 million, an increase of $1,043.2 million
from 2018. This increase was driven primarily by the receipt of $795 million of insurance recoveries in 2019 related to the Greater
Lawrence Incident and approximately $220 million lower cash spend for the Greater Lawrence Incident in 2019. Refer to Note
19, "Other Commitments and Contingencies" in the Notes to Consolidated Financial Statements for further information related
to the Greater Lawrence Incident.
Pension and Other Postretirement Plan Funding. In 2019, we contributed $2.9 million to our pension plans and $23.0 million
to our other postretirement benefit plans. In 2018, we contributed $2.9 million to our pension plans and $21.0 million to our other
postretirement benefit plans. Given the current funded status of the pension plans, and barring unforeseen market volatility that
may negatively impact the valuation of our plan assets, we do not believe additional material contributions to our pension plans
will be required for the foreseeable future.
Income Taxes. Rates for our regulated customers include provisions for the collection of U.S. federal income taxes. The reduction
in the U.S. federal corporate income tax rate as a result of the TCJA led to a decrease in the amount billed to customers through
rates, ultimately resulting in lower cash collections from operating activities. In addition, we are required to pass back to customers
“excess deferred taxes” which represent amounts collected from customers in the past to cover deferred tax liabilities which, as
a result of the passage of the TCJA, are now less than the originally billed amounts. Approximately $1.5 billion of excess deferred
taxes was recorded as a regulatory liability as of December 31, 2017 as a result of implementing the TCJA. The majority of this
balance related to temporary book-to-tax differences on utility property protected by IRS normalization rules; this portion of the
excess deferred taxes balance will be passed back to customers over the remaining average useful life of the associated property
as required by the TCJA. The remainder of the excess deferred tax balance is passed back over periods determined by our state
utility commissions. The pass back of excess deferred taxes has been approved in all our jurisdictions. As of December 31, 2019,
we have approximately $1.3 billion of remaining regulatory liabilities associated with excess deferred taxes.
As of December 31, 2019, we have a deferred tax asset of $657.1 million related to a federal NOL carryforward, of which $406.1
million relates to years prior to the implementation of the TCJA. As a result of being in an NOL position, we were not required
to make any cash payments for federal income tax purposes during the three years ended December 31, 2019. The carryforward
periods for pre-TCJA tax benefits expire in various tax years from 2028 to 2037; however, we expect to fully utilize the carryforward
benefit prior to its expiration. According to the TCJA, utilization of NOL carryforwards generated after December 31, 2017 do
not expire but are limited to 80% of current year taxable income. Accordingly, we may be required to make cash payments for
federal income taxes in future years despite having NOL carryforwards in excess of current taxes payable.
40
Table of Contents
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS (continued)
NISOURCE INC.
Investing Activities
Our cash used for investing activities varies year over year primarily as a result of changes in the level of annual capital expenditures.
The table below reflects capital expenditures and certain other investing activities by segment for 2019, 2018 and 2017.
(in millions)
Gas Distribution Operations
System Growth and Tracker
Maintenance
Total Gas Distribution Operations
Electric Operations
System Growth and Tracker
Maintenance
2019
2018(3)
2017
$
1,006.1
$
897.5
$
374.3
1,380.3
279.5
189.4
417.8
1,315.3
346.0
153.3
909.2
216.4
1,125.6
435.3
157.1
Total Electric Operations
Corporate and Other Operations - Maintenance(1)
Total(2)
(1) Corporate and Other capital expenditures were zero in 2018 as specific IT assets were leased in 2018. Certain IT and other maintenance related assets were
purchased in 2017 and 2019.
(2)Amounts differ from those presented on the Statements of Consolidated Cash Flows primarily due to the capitalized portion of the Corporate Incentive Plan
payout, inclusion of capital expenditures included in current liabilities and AFUDC Equity.
(3) The 2018 capital expenditures for Gas Distribution Operations reflects reclassifying the Greater Lawrence Incident pipeline replacement from system growth
and tracker to maintenance.
1,753.8
1,867.8
1,814.6
499.3
468.9
592.4
18.6
35.8
—
$
$
$
For 2019, capital expenditures and certain other investing activities were $1,867.8 million, which was $53.2 million higher than
the 2018 capital program. This increased spending is primarily due to growth, safety and system modernization projects.
For 2018, capital expenditures and certain other investing activities were $1,814.6 million, which was $60.8 million higher than
the 2017 capital program. This increased spending is due in part to costs associated with the Greater Lawrence Incident pipeline
replacement, gas transmission projects, environmental investments and system modernization projects across all seven states in
our operating area.
For 2020, we project to invest approximately $1.8 to $1.9 billion in our capital program. This projected level of spend is consistent
with 2019 spend levels and is expected to focus on growth, safety, and modernization projects across our operating area.
Financing Activities
Short-term Debt. Refer to Note 15, “Short-Term Borrowings,” in the Notes to Consolidated Financial Statements for information
on short-term debt.
Long-term Debt. Refer to Note 14, “Long-Term Debt,” in the Notes to Consolidated Financial Statements for information on long-
term debt.
Net Available Liquidity. As of December 31, 2019, an aggregate of $1,409.1 million of net liquidity was available, including cash
and credit available under the revolving credit facility and accounts receivable securitization programs.
41
Table of Contents
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS (continued)
NISOURCE INC.
The following table displays NiSource's liquidity position as of December 31, 2019 and 2018:
Year Ended December 31, (in millions)
Current Liquidity
Revolving Credit Facility
Accounts Receivable Program(1)
Less:
Commercial Paper
Accounts Receivable Program Utilized
Letters of Credit Outstanding Under Credit Facility
Add:
Cash and Cash Equivalents
2019
2018
$
1,850.0 $
353.2
1,850.0
399.2
570.0
353.2
10.2
139.3
1,409.1 $
978.0
399.2
10.2
112.8
974.6
Net Available Liquidity
(1)Represents the lesser of the seasonal limit or maximum borrowings supportable by the underlying receivables.
$
Debt Covenants. We are subject to a financial covenant under our revolving credit facility and term loan agreement, which requires
us to maintain a debt to capitalization ratio that does not exceed 70%. A similar covenant in a 2005 private placement note purchase
agreement requires us to maintain a debt to capitalization ratio that does not exceed 75%. As of December 31, 2019, the ratio was
61.7%.
Sale of Trade Accounts Receivables. Refer to Note 18, “Transfers of Financial Assets,” in the Notes to Consolidated Financial
Statements for information on the sale of trade accounts receivable.
Credit Ratings. The credit rating agencies periodically review our ratings, taking into account factors such as our capital structure
and earnings profile. The following table includes our and certain of our subsidiaries' credit ratings and ratings outlook as of
December 31, 2019.
A credit rating is not a recommendation to buy, sell or hold securities, and may be subject to revision or withdrawal at any time
by the assigning rating organization.
NiSource
NIPSCO
Columbia of Massachusetts
Commercial Paper
S&P
Moody's
Fitch
Rating
BBB+
BBB+
BBB+
A-2
Outlook
Negative
Negative
Negative
Negative
Rating
Outlook
Baa2
Baa1
Baa2
P-2
Stable
Stable
Stable
Stable
Rating
BBB
BBB
Outlook
Stable
Stable
Not rated
Not rated
F2
Stable
Certain of our subsidiaries have agreements that contain “ratings triggers” that require increased collateral if our credit ratings or
the credit ratings of certain of our subsidiaries are below investment grade. These agreements are primarily for insurance purposes
and for the physical purchase or sale of power. As of December 31, 2019, the collateral requirement that would be required in the
event of a downgrade below the ratings trigger levels would amount to approximately $72.1 million. In addition to agreements
with ratings triggers, there are other agreements that contain “adequate assurance” or “material adverse change” provisions that
could necessitate additional credit support such as letters of credit and cash collateral to transact business.
Equity. Our authorized capital stock consists of 620,000,000 shares, $0.01 par value, of which 600,000,000 are common stock
and 20,000,000 are preferred stock. As of December 31, 2019, 382,135,680 shares of common stock and 440,000 shares of preferred
stock were outstanding. For more information regarding our common and preferred stock, see Note 12, "Equity," in the Notes to
Consolidated Financial Statements.
42
Table of Contents
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS (continued)
NISOURCE INC.
Contractual Obligations. We have certain contractual obligations requiring payments at specified periods. The obligations include
long-term debt, lease obligations, energy commodity contracts and obligations for various services including pipeline capacity
and outsourcing of IT services. The total contractual obligations in existence at December 31, 2019 and their maturities were:
(in millions)
Long-term debt (1)
Interest payments on long-term debt
Finance leases(2)
Operating leases(3)
Energy commodity contracts(4)
Service obligations:
Pipeline service obligations
IT service obligations
Other service obligations(5)
Other liabilities
Total
2020
2021
2022
2023
2024
After
$
7,738.6
$
— $
63.6
$
530.0
$
600.0
$
— $
6,545.0
6,214.2
325.9
79.1
95.9
3,450.7
153.2
59.8
27.3
342.0
27.2
15.6
65.5
605.0
63.6
45.8
27.3
340.7
27.3
9.4
30.4
590.1
49.4
14.0
—
337.1
26.8
8.2
—
546.8
38.0
—
—
311.1
23.1
7.6
—
299.9
19.9
6.6
—
4,583.4
201.6
31.7
—
357.2
237.5
1,114.1
1.1
—
—
1.1
—
—
—
—
—
$
$ 18,144.7
Total contractual obligations
(1) Long-term debt balance excludes unamortized issuance costs and discounts of $70.5 million.
(2) Finance lease payments shown above are inclusive of interest totaling $108.3 million.
(3) Operating lease payments shown above are inclusive of interest totaling $14.3 million. Operating lease balances do not include obligations for possible fleet
vehicle lease renewals beyond the initial lease term. While we have the ability to renew these leases beyond the initial term, we are not reasonably certain (as that
term is defined in ASC 842) to do so. If we were to continue the fleet vehicle leases outstanding at December 31, 2019, payments would be $34.5 million in 2020,
$28.3 million in 2021, $23.4 million in 2022, $19.9 million in 2023, $15.2 million in 2024 and $15.2 million thereafter.
(4)In January 2020, NIPSCO signed new coal contract commitments of $14.4 million for 2020. These contracts are not included above.
(5)In February 2020, NIPSCO signed a new railcar coal transportation contract commitment of $12.0 million for 2020. This contract is not included above.
$ 12,475.8
1,486.9
1,192.0
1,124.9
1,300.1
565.0
$
$
$
$
Our calculated estimated interest payments for long-term debt is based on the stated coupon and payment dates. For 2020, we
project that we will be required to make interest payments of approximately $368.2 million, which includes $342.0 million of
interest payments related to our long-term debt outstanding as of December 31, 2019. At December 31, 2019, we had $1,773.2
million in short-term borrowings outstanding.
Our expected payments included within “Other liabilities” in the table of contractual commitments above contains employer
contributions to pension and other postretirement benefits plans expected to be made in 2020. Plan contributions beyond 2020 are
dependent upon a number of factors, including actual returns on plan assets, which cannot be reliably estimated at this time. In
2020, we expect to make contributions of approximately $3.0 million to our pension plans and approximately $24.0 million to
our postretirement medical and life plans. Refer to Note 11, “Pension and Other Postretirement Benefits,” in the Notes to
Consolidated Financial Statements for more information.
We cannot reasonably estimate the settlement amounts or timing of cash flows related to long-term obligations classified as “Total
Other Liabilities” on the Consolidated Balance Sheets, other than those described above.
We also have obligations associated with income, property, gross receipts, franchise, payroll, sales and use, and various other taxes
and expect to make tax payments of approximately $247.1 million in 2020, which are not included in the table above. In addition,
we have uncertain income tax positions that are not included in the table above as we are unable to predict when the matters will
be resolved. Refer to Note 10, "Income Taxes," in the Notes to Consolidated Financial Statements for more information.
Refer to Note 19-A, “Contractual Obligations,” in the Notes to Consolidated Financial Statements for further information.
In January 2019, NIPSCO executed two 20 year PPAs to purchase 100% of the output from renewable generation facilities at a
fixed price per MWh. Payments under the PPAs will not begin until the associated generation facilities are constructed by the
owner / seller which is currently scheduled to be complete by the end of 2020 for one facility. Payments that will be made under
the agreements are not included in the table of contractual commitments above as there are no minimum payment obligations
under the agreements. NIPSCO has filed a notice with the IURC of its intention not to move forward with one of its approved
PPAs due to the failure to meet a condition precedent in the agreement as a result of local zoning restrictions. See Note 19-E,
“Other Matters - NIPSCO 2018 Integrated Resource Plan,” in the Notes to Consolidated Financial Statements for additional
information.
In January 2019, NIPSCO executed a BTA with a developer to construct a renewable generation facility with a nameplate capacity
of approximately 100 MW; construction of the facility is expected to be completed by the end of 2020. In October 2019, NIPSCO
43
Table of Contents
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS (continued)
NISOURCE INC.
executed a BTA with a developer to construct an additional renewable generation facility with a nameplate capacity of approximately
300 MW; construction of this facility is expected to be completed by the end of 2021. Payments under these agreements are not
included in the table of contractual commitments as NIPSCO's purchase requirement under these BTAs is dependent on satisfactory
approval of the BTAs by the IURC, successful execution of agreements with a tax equity partner, and timely completion of
construction. See Note 19-E, “Other Matters - NIPSCO 2018 Integrated Resource Plan,” in the Notes to Consolidated Financial
Statements for additional information.
Off-Balance Sheet Arrangements
We, along with certain of our subsidiaries, enter into various agreements providing financial or performance assurance to third
parties on behalf of certain subsidiaries. Such agreements include guarantees and stand-by letters of credit.
Refer to Note 19, “Other Commitments and Contingencies,” in the Notes to Consolidated Financial Statements for additional
information about such arrangements.
Market Risk Disclosures
Risk is an inherent part of our businesses. The extent to which we properly and effectively identify, assess, monitor and manage
each of the various types of risk involved in our businesses is critical to our profitability. We seek to identify, assess, monitor and
manage, in accordance with defined policies and procedures, the following principal market risks that are involved in our businesses:
commodity price risk, interest rate risk and credit risk. Risk management for us is a multi-faceted process with oversight by the
Risk Management Committee that requires constant communication, judgment and knowledge of specialized products and markets.
Our senior management takes an active role in the risk management process and has developed policies and procedures that require
specific administrative and business functions to assist in the identification, assessment and control of various risks. These may
include, but are not limited to market, operational, financial, compliance and strategic risk types. In recognition of the increasingly
varied and complex nature of the energy business, our risk management process, policies and procedures continue to evolve and
are subject to ongoing review and modification.
Commodity Price Risk
We are exposed to commodity price risk as a result of our subsidiaries’ operations involving natural gas and power. To manage
this market risk, our subsidiaries use derivatives, including commodity futures contracts, swaps, forwards and options. We do not
participate in speculative energy trading activity.
Commodity price risk resulting from derivative activities at our rate-regulated subsidiaries is limited, since regulations allow
recovery of prudently incurred purchased power, fuel and gas costs through the rate-making process, including gains or losses on
these derivative instruments. If states should explore additional regulatory reform, these subsidiaries may begin providing services
without the benefit of the traditional rate-making process and may be more exposed to commodity price risk.
Our subsidiaries are required to make cash margin deposits with their brokers to cover actual and potential losses in the value of
outstanding exchange traded derivative contracts. The amount of these deposits, some of which is reflected in our restricted cash
balance, may fluctuate significantly during periods of high volatility in the energy commodity markets.
Refer to Note 9, "Risk Management Activities," in the Notes to the Consolidated Financial Statements for further information on
our commodity price risk assets and liabilities as of December 31, 2019 and 2018.
Interest Rate Risk
We are exposed to interest rate risk as a result of changes in interest rates on borrowings under our revolving credit agreement,
commercial paper program, term loan agreement and accounts receivable programs, which have interest rates that are indexed to
short-term market interest rates. Based upon average borrowings and debt obligations subject to fluctuations in short-term market
interest rates, an increase (or decrease) in short-term interest rates of 100 basis points (1%) would have increased (or decreased)
interest expense by $19.0 million and $13.3 million for 2019 and 2018, respectively. We are also exposed to interest rate risk as
a result of changes in benchmark rates that can influence the interest rates of future debt issuances.
Refer to Note 9, "Risk Management Activities," in the Notes to Consolidated Financial Statements for further information on our
interest rate risk assets and liabilities as of December 31, 2019 and 2018.
44
Table of Contents
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS (continued)
NISOURCE INC.
Credit Risk
Due to the nature of the industry, credit risk is embedded in many of our business activities. Our extension of credit is governed
by a Corporate Credit Risk Policy. In addition, Risk Management Committee guidelines are in place which document management
approval levels for credit limits, evaluation of creditworthiness, and credit risk mitigation efforts. Exposures to credit risks are
monitored by the risk management function which is independent of commercial operations. Credit risk arises due to the possibility
that a customer, supplier or counterparty will not be able or willing to fulfill its obligations on a transaction on or before the
settlement date. For derivative-related contracts, credit risk arises when counterparties are obligated to deliver or purchase defined
commodity units of gas or power to us at a future date per execution of contractual terms and conditions. Exposure to credit risk
is measured in terms of both current obligations and the market value of forward positions net of any posted collateral such as
cash and letters of credit.
We closely monitor the financial status of our banking credit providers. We evaluate the financial status of our banking partners
through the use of market-based metrics such as credit default swap pricing levels, and also through traditional credit ratings
provided by major credit rating agencies.
Other Information
Critical Accounting Policies
We apply certain accounting policies based on the accounting requirements discussed below that have had, and may continue to
have, significant impacts on our operations and Consolidated Financial Statements.
Basis of Accounting for Rate-Regulated Subsidiaries. ASC Topic 980, Regulated Operations, provides that rate-regulated
subsidiaries account for and report assets and liabilities consistent with the economic effect of the way in which regulators establish
rates, if the rates established are designed to recover the costs of providing the regulated service and if the competitive environment
makes it probable that such rates can be charged and collected. Certain expenses and credits subject to utility regulation or rate
determination normally reflected in income are deferred on the Consolidated Balance Sheets and are recognized in income as the
related amounts are included in service rates and recovered from or refunded to customers. The total amounts of regulatory assets
and liabilities reflected on the Consolidated Balance Sheets were $2,239.6 million and $2,512.2 million at December 31, 2019,
and $2,237.5 million and $2,660.0 million at December 31, 2018, respectively. For additional information, refer to Note 8,
“Regulatory Matters,” in the Notes to Consolidated Financial Statements.
In the event that regulation significantly changes the opportunity for us to recover our costs in the future, all or a portion of our
regulated operations may no longer meet the criteria for the application of ASC Topic 980, Regulated Operations. In such event,
a write-down of all or a portion of our existing regulatory assets and liabilities could result. If transition cost recovery is approved
by the appropriate regulatory bodies that would meet the requirements under GAAP for continued accounting as regulatory assets
and liabilities during such recovery period, the regulatory assets and liabilities would be reported at the recoverable amounts. If
we were unable to continue to apply the provisions of ASC Topic 980, Regulated Operations, we would be required to apply the
provisions of ASC Topic 980-20, Discontinuation of Rate-Regulated Accounting. In management’s opinion, our regulated
subsidiaries will be subject to ASC Topic 980, Regulated Operations for the foreseeable future.
Certain of the regulatory assets reflected on our Consolidated Balance Sheets require specific regulatory action in order to be
included in future service rates. Although recovery of these amounts is not guaranteed, we believe that these costs meet the
requirements for deferral as regulatory assets. Regulatory assets requiring specific regulatory action amounted to $307.2 million
at December 31, 2019. If we determine that the amounts included as regulatory assets were not recoverable, a charge to income
would immediately be required to the extent of the unrecoverable amounts.
The passage of the TCJA into law in December 2017 necessitated the remeasurement of our deferred income tax balances to reflect
the change in the statutory federal tax rate from 35% to 21%. For our regulated entities, substantially all of the impact of this
remeasurement was recorded to a regulatory liability and is being passed backed to customers, as established during the rate making
process. For additional information, refer to Note 8, "Regulatory Matters," and Note 10, "Income Taxes," in the Notes to
Consolidated Financial Statements.
As discussed in Note 19-E, "Other Matters - Greater Lawrence Pipeline Replacement," since the Greater Lawrence Incident and
through December 31, 2019, we have invested approximately $258 million of capital spend for the pipeline replacement in the
affected communities; this work was completed in 2019. We maintain property insurance for gas pipelines and other applicable
property. Columbia of Massachusetts has filed a proof of loss with its property insurer for the full cost of the pipeline replacement.
In January 2020, we filed a lawsuit against the property insurer, seeking payment of our property claim. We are currently unable
45
Table of Contents
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS (continued)
NISOURCE INC.
to predict the timing or amount of any insurance recovery under the property policy. The recovery of any capital investment not
reimbursed through insurance will be addressed in a future regulatory proceeding; a future regulatory proceeding is dependent on
the outcome of the sale of the Massachusetts Business. The outcome of such a proceeding (if any) is uncertain. In accordance with
ASC 980-360, if it becomes probable that a portion of the pipeline replacement cost will not be recoverable through customer
rates and an amount can be reasonably estimated, we will reduce our regulated plant balance for the amount of the probable
disallowance and record an associated charge to earnings. This could result in a material adverse effect to our financial condition,
results of operations and cash flows. Additionally, if a rate order is received allowing recovery of the investment with no or reduced
return on investment, a loss on disallowance may be required.
Pension and Postretirement Benefits. We have defined benefit plans for both pension and other postretirement benefits. The
calculation of the net obligations and annual expense related to the plans requires a significant degree of judgment regarding the
discount rates to be used in bringing the liabilities to present value, expected long-term rates of return on plan assets, health care
trend rates, and mortality rates, among other assumptions. Due to the size of the plans and the long-term nature of the associated
liabilities, changes in the assumptions used in the actuarial estimates could have material impacts on the measurement of the net
obligations and annual expense recognition. Differences between actuarial assumptions and actual plan results are deferred into
AOCI or a regulatory balance sheet account, depending on the jurisdiction of our entity. These deferred gains or losses are then
amortized into the income statement when the accumulated differences exceed 10% of the greater of the projected benefit obligation
or the fair value of plan assets (known in GAAP as the “corridor” method) or when settlement accounting is triggered.
The discount rates, expected long-term rates of return on plan assets, health care cost trend rates and mortality rates are critical
assumptions. Methods used to develop these assumptions are described below. While a third party actuarial firm assists with the
development of many of these assumptions, we are ultimately responsible for selecting the final assumptions.
The discount rate is utilized principally in calculating the actuarial present value of pension and other postretirement benefit
obligations and net periodic pension and other postretirement benefit plan costs. Our discount rates for both pension and other
postretirement benefits are determined using spot rates along an AA-rated above median yield curve with cash flows matching the
expected duration of benefit payments to be made to plan participants.
The expected long-term rate of return on plan assets is a component utilized in calculating annual pension and other postretirement
benefit plan costs. We estimate the expected return on plan assets by evaluating expected bond returns, equity risk premiums, target
asset allocations, the effects of active plan management, the impact of periodic plan asset rebalancing and historical performance.
We also consider the guidance from our investment advisors in making a final determination of our expected rate of return on
assets.
For measurement of 2020 net periodic benefit cost, we selected an expected pre-tax long-term rate of return of 5.70% and 5.67%
for our pension and other postretirement benefit plan assets, respectively.
We estimate the assumed health care cost trend rate, which is used in determining our other postretirement benefit net expense,
based upon our actual health care cost experience, the effects of recently enacted legislation, third-party actuarial surveys and
general economic conditions.
We use the Society of Actuaries’ most recently published mortality data in developing a best estimate of mortality as part of the
calculation of the pension and other postretirement benefit obligations.
46
Table of Contents
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS (continued)
NISOURCE INC.
The following tables illustrate the effects of changes in these actuarial assumptions while holding all other assumptions constant:
Change in Assumptions (in millions)
+50 basis points change in discount rate
-50 basis points change in discount rate
+50 basis points change in health care trend rates
-50 basis points change in health care trend rates
Change in Assumptions (in millions)
+50 basis points change in discount rate
-50 basis points change in discount rate
+50 basis points change in expected long-term rate of return
on plan assets
-50 basis points change in expected long-term rate of return
on plan assets
+50 basis points change in health care trend rates
-50 basis points change in health care trend rates
(1)Before labor capitalization and regulatory deferrals.
$
$
Impact on December 31, 2019 Projected Benefit Obligation
Increase/(Decrease)
Pension Benefits
Other Postretirement Benefits
(29.0)
31.8
(89.9) $
97.7
15.0
(13.1)
Impact on 2019 Expense Increase/(Decrease)(1)
Pension Benefits
Other Postretirement Benefits
(1.8) $
1.9
(8.9)
8.9
0.3
0.7
(1.2)
1.2
0.6
(0.5)
In January 2017, we changed the method used to estimate the service and interest components of net periodic benefit cost for
pension and other postretirement benefits. This change, compared to the previous method, resulted in a decrease in the actuarially-
determined service and interest cost components. Historically, we estimated service and interest cost utilizing a single weighted-
average discount rate derived from the yield curve used to measure the benefit obligation at the beginning of the period. For fiscal
2017 and beyond, we now utilize a full yield curve approach to estimate these components by applying the specific spot rates
along the yield curve used in the determination of the benefit obligation to the relevant projected cash flows. For further discussion
of our pension and other postretirement benefits, see Note 11, “Pension and Other Postretirement Benefits,” in the Notes to
Consolidated Financial Statements.
Goodwill and Intangible Assets. We have seven goodwill reporting units, comprised of the seven state operating companies within
the Gas Distribution Operations reportable segment. Our goodwill assets at December 31, 2019 were $1,486 million, most of
which resulted from the acquisition of Columbia on November 1, 2000.
As required by GAAP, we test for impairment of goodwill on an annual basis and on an interim basis when events or circumstances
indicate that a potential impairment may exist. Our annual goodwill test takes place in the second quarter of each year and was
performed on May 1, 2019. A qualitative ("step 0") test was completed on May 1, 2019 for all reporting units other than our
Columbia of Massachusetts reporting unit. In the Step 0 analysis, we assessed various assumptions, events and circumstances that
would have affected the estimated fair value of the applicable reporting units as compared to their baseline May 1, 2016 “step 1”
fair value measurement. The results of this assessment indicated that it is not more likely than not that these reporting units fair
values are less than their reporting unit carrying values; therefore, no “step 1” analysis was required.
The results of our Columbia of Massachusetts reporting unit were negatively impacted by the Greater Lawrence Incident (see Note
19-C, "Legal Proceedings," in the Notes to Consolidated Financial Statements). As a result, we completed a quantitative "step 1"
analysis for the May 1, 2019 goodwill analysis for this reporting unit. Consistent with our historical impairment testing of goodwill,
fair value of this reporting unit was determined based on a weighting of income and market approaches. These approaches require
significant judgments including appropriate long-term growth rates and discount rates for the income approach and appropriate
multiples of earnings for peer companies and control premiums for the market approach. The discount rates were derived using
peer company data compiled with the assistance of a third party valuation services firm. The discount rates used are subject to
change based on changes in tax rates at both the state and federal level, debt and equity ratios at each reporting unit and general
economic conditions. The long-term growth rate was derived by evaluating historic growth rates, new business and investment
opportunities beyond the near term horizon. The long-term growth rate is subject to change depending on inflationary impacts to
47
Table of Contents
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS (continued)
NISOURCE INC.
the U.S. economy and the individual business environments in which each reporting unit operates. The Step 1 analysis performed
indicated that the fair value of the Columbia of Massachusetts reporting unit exceeds its carrying value. As a result, no impairment
charge was recorded as of the May 1, 2019 test date.
Although our annual impairment test is performed during the second quarter, we continue to monitor changes in circumstances
that may indicate that it is more likely than not that the fair value of our reporting units is less than the reporting unit carrying
value. During the fourth quarter of 2019, in connection with the preparation of the year-end financial statements, we assessed
matters related to Columbia of Massachusetts. While there was no single determinative event or factor, the consideration in totality
of several factors that developed during the fourth quarter of 2019 led us to conclude that it was more likely than not that the fair
value of the Columbia of Massachusetts reporting unit was below its carrying value. These factors included: (i) increased
Massachusetts DPU regulatory enforcement activity related to Columbia of Massachusetts during the fourth quarter, including (a)
an order imposing work restrictions on Columbia of Massachusetts, impacting Columbia of Massachusetts' infrastructure
replacement program, (b) two orders opening public investigations into Columbia of Massachusetts related to the Greater Lawrence
Incident and restoration efforts following the incident, and (c) an order defining the scope of the Massachusetts DPU's investigation
into the preparation and response of Columbia of Massachusetts related to the incident; (ii) increased uncertainty as to the ability
of Columbia of Massachusetts to execute its growth strategy, including utility infrastructure investments, and to obtain timely
regulatory outcomes with reasonable rates of return; (iii) further damage to Columbia of Massachusetts' reputation as a result of
concerns related to service lines abandoned during the restoration work following the Greater Lawrence Incident and the gas
release event in Lawrence, Massachusetts on September 27, 2019; and (iv) a potential sale of the Massachusetts Business. See
Note 19, "Other Commitments and Contingencies - C. Legal Proceedings," in the Notes to Consolidated Financial Statements for
more information regarding Massachusetts DPU regulatory enforcement activity and Note 26, "Subsequent Event," in the Notes
to Consolidated Financial Statements for more information regarding the potential sale of the Massachusetts Business.
As a result, a new impairment analysis was required for our Columbia of Massachusetts reporting unit. This analysis used a weighted
average of income and market approaches for calculating fair value. The income approach calculated discounted cash flows using
updated cash flow projections, discount rates and return on equity assumptions. The market approach applied a combination of
comparable company multiples and comparable transactions and used updated cash flow projections. While certain assumptions,
such as market multiples, remained unchanged in the year-end test, our cash flow projections, return on equity and rate case timing
assumptions were all unfavorably updated at year-end compared to the May 1, 2019 test. The effects of these unfavorable
developments were greater than the favorable change in weighted average cost of capital between the two tests. The year-end
impairment analysis indicated that the fair value of the Columbia of Massachusetts reporting unit was below its carrying value.
As a result, we reduced the Columbia of Massachusetts reporting unit goodwill balance to zero and recognized a goodwill impairment
charge totaling $204.8 million, which is non-deductible for tax purposes.
Our intangible assets, apart from goodwill, consist of franchise rights. Franchise rights were identified as part of the purchase price
allocations associated with the acquisition in February 1999 of Columbia of Massachusetts. We review our definite-lived intangible
assets for impairment when events or changes in circumstances indicate its fair value might be below its carrying amount.
During the fourth quarter of 2019, in connection with the preparation of the year-end financial statements, we assessed the changes
in circumstances that occurred during the quarter to determine if it was more likely than not that the fair value of the franchise
rights was below its carrying amount. These factors were the same fourth quarter circumstances outlined in the goodwill impairment
discussion above. As a result, we performed a year-end impairment test in which we compared the book value of Columbia of
Massachusetts to its undiscounted future cash flow and estimated fair value. With this analysis, we determined that the fair value
of the franchise rights was zero. Therefore, we wrote off the entire franchise rights book value, which resulted in an impairment
charge totaling $209.7 million. See Note 6, "Goodwill and Other Intangible Assets," in the Notes to Consolidated Financial
Statements for more information.
Revenue Recognition. Revenue is recorded as products and services are delivered. Utility revenues are billed to customers monthly
on a cycle basis. Revenues are recorded on the accrual basis and include estimates for electricity and gas delivered but not billed.
We adopted the provisions of ASC 606 beginning on January 1, 2018 using a modified retrospective method, which was applied
to all contracts. No material adjustments were made to January 1, 2018 opening balances and no material changes in the amount
or timing of future revenue recognition occurred as a result of the adoption of ASC 606. Refer to Note 3 "Revenue Recognition,"
in the Notes to Consolidated Financial Statements.
Recently Issued Accounting Pronouncements
Refer to Note 2, "Recent Accounting Pronouncements," in the Notes to Consolidated Financial Statements.
48
Table of Contents
ITEM 7A. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK
NISOURCE INC.
Quantitative and Qualitative Disclosures about Market Risk are reported in Item 7. “Management’s Discussion and Analysis of
Financial Condition and Results of Operations – Market Risk Disclosures.”
49
Table of Contents
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA
NISOURCE INC.
Index
Report of Independent Registered Public Accounting Firm ................................................................................................
Statements of Consolidated Income (Loss)..........................................................................................................................
Statements of Consolidated Comprehensive Income (Loss)................................................................................................
Consolidated Balance Sheets ...............................................................................................................................................
Statements of Consolidated Cash Flows ..............................................................................................................................
Statements of Consolidated Stockholders' Equity................................................................................................................
Notes to Consolidated Financial Statements ........................................................................................................................
1. Nature of Operations and Summary of Significant Accounting Policies ....................................................................
2. Recent Accounting Pronouncements...........................................................................................................................
3. Revenue Recognition...................................................................................................................................................
4. Earnings Per Share ......................................................................................................................................................
5. Property, Plant and Equipment ....................................................................................................................................
6. Goodwill and Other Intangible Assets.........................................................................................................................
7. Asset Retirement Obligations ......................................................................................................................................
8. Regulatory Matters ......................................................................................................................................................
9. Risk Management Activities........................................................................................................................................
10. Income Taxes .............................................................................................................................................................
11. Pension and Other Postretirement Benefits ...............................................................................................................
12. Equity ........................................................................................................................................................................
13. Share-Based Compensation.......................................................................................................................................
14. Long-Term Debt ........................................................................................................................................................
15. Short-Term Borrowings.............................................................................................................................................
16. Leases ........................................................................................................................................................................
17. Fair Value...................................................................................................................................................................
18. Transfers of Financial Assets.....................................................................................................................................
19. Other Commitments and Contingencies....................................................................................................................
20. Accumulated Other Comprehensive Loss .................................................................................................................
21. Other, Net ..................................................................................................................................................................
22. Interest Expense, Net.................................................................................................................................................
23. Segments of Business ................................................................................................................................................
24. Quarterly Financial Data (Unaudited) .......................................................................................................................
25. Supplemental Cash Flow Information.......................................................................................................................
26. Subsequent Event ......................................................................................................................................................
Schedule II............................................................................................................................................................................
Page
51
54
55
56
58
59
61
61
64
65
68
69
69
71
71
79
81
83
95
98
101
102
103
106
109
110
119
119
120
120
122
122
123
124
50
Table of Contents
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (continued)
NISOURCE INC.
REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM
To the stockholders and the Board of Directors of NiSource Inc.
Opinion on the Financial Statements
We have audited the accompanying consolidated balance sheets of NiSource Inc. and subsidiaries (the "Company") as of December
31, 2019 and 2018, the related statements of consolidated income (loss), comprehensive income (loss), stockholders' equity, and
cash flows for each of the three years in the period ended December 31, 2019, and the related notes and the schedule listed in the
Index at Item 15 (collectively referred to as the "financial statements"). In our opinion, the financial statements present fairly, in
all material respects, the financial position of the Company as of December 31, 2019 and 2018, and the results of its operations
and its cash flows for each of the three years in the period ended December 31, 2019, in conformity with accounting principles
generally accepted in the United States of America.
We have also audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States)
(PCAOB), the Company's internal control over financial reporting as of December 31, 2019, based on criteria established in Internal
Control - Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission and
our report dated February 27, 2020, expressed an unqualified opinion on the Company's internal control over financial reporting.
Basis for Opinion
These financial statements are the responsibility of the Company's management. Our responsibility is to express an opinion on the
Company's financial statements based on our audits. We are a public accounting firm registered with the 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
audit to obtain reasonable assurance about whether the financial statements are free of material misstatement, whether due to error
or fraud. Our audits included performing procedures to assess the risks of material misstatement of the 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 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 financial
statements. We believe that our audits provide a reasonable basis for our opinion.
Critical Audit Matters
The critical audit matters communicated below are matters arising from the current-period audit of the financial statements that
were communicated or required to be communicated to the audit committee and that (1) relate to accounts or disclosures that are
material to the financial statements and (2) involved our especially challenging, subjective, or complex judgments. The
communication of critical audit matters does not alter in any way our opinion on the financial statements, taken as a whole, and
we are not, by communicating the critical audit matters below, providing separate opinions on the critical audit matters or on the
accounts or disclosures to which they relate.
Impact of Rate Regulation on the Financial Statements - Refer to Notes 1, 8, 19, and 26 to the financial statements
Critical Audit Matter Description
Certain subsidiaries of NiSource Inc. are fully regulated natural gas and electric utility companies serving customers in seven
states. These rate-regulated subsidiaries account for and report assets and liabilities consistent with the economic effect of the
manner in which regulators establish rates, if the rates established are designed to recover the costs of providing the regulated
service and it is probable that such rates can be charged to and collected from customers. Certain expenses and credits subject to
utility regulation or rate determination normally reflected in income are deferred on the consolidated balance sheets and are later
recognized in income as the related amounts are included in customer rates and recovered from or refunded to customers.
Through December 31, 2019, the Company invested approximately $258 million of capital spend for the Greater Lawrence Incident
pipeline replacement. As of December 31, 2019, the Company determined that a disallowance of the Greater Lawrence Incident
pipeline replacement capital expenditures was not probable. On February 26, 2020, the Company and its wholly-owned subsidiary,
Columbia of Massachusetts (CMA), agreed to sell substantially all of CMA's utility property, plant, and equipment (including the
Greater Lawrence Incident pipeline replacement assets) with other specified assets and liabilities, to a third party. The Company
51
Table of Contents
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (continued)
NISOURCE INC.
REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM
estimates that the total pre-tax loss resulting from this sale will be approximately $360 million, based on December 31, 2019 asset
and liability balances and estimated transaction costs.
We identified the accounting for rate-regulated subsidiaries as a critical audit matter due to the significant judgments made by
management to support its assertions about impacted account balances and disclosures and the high degree of subjectivity involved
in assessing the impact of future regulatory orders on the financial statements. Management judgments include assessing (1) the
likelihood of recovery in future rates of incurred costs, (2) the likelihood of refund of amounts previously collected from customers,
and (3) the probability of recovery of amounts capitalized related to the Greater Lawrence Incident pipeline replacement. Given
that management’s accounting judgments are based on assumptions about the outcome of future decisions by regulatory
commissions, auditing these judgments required specialized knowledge of accounting for rate regulation and the rate making
process due its inherent complexities.
How the Critical Audit Matter Was Addressed in the Audit
Our audit procedures related to the uncertainty of future decisions by regulatory commissions included the following, among
others:
• We tested the effectiveness of management’s controls over the evaluation of the likelihood of (1) the recovery in future rates
of costs incurred as property, plant, and equipment and deferred as regulatory assets, and (2) a refund or a future reduction in
rates that should be reported as regulatory liabilities. We also tested the effectiveness of management’s controls over the initial
recognition of amounts as property, plant, and equipment, including the Greater Lawrence Incident pipeline replacement;
regulatory assets or liabilities; and the monitoring and evaluation of regulatory developments, that may affect the likelihood
of recovering costs in future rates or of a future reduction in rates.
• We evaluated the Company’s disclosures related to the impacts of rate regulation, including the balances recorded and regulatory
developments.
• We read relevant regulatory orders issued by regulatory commissions, regulatory statutes, interpretations, filings made by
interveners, and other publicly available information to assess the likelihood of recovery in future rates or of a future reduction
in rates based on precedence of regulatory commissions’ treatment of similar costs under similar circumstances. We evaluated
the external information and compared it to management’s recorded regulatory asset and liability balances for completeness.
• For regulatory matters in process, including those that could impact the Greater Lawrence Incident pipeline replacement, we
inspected the Company’s filings with regulatory commissions and the filings with regulatory commissions by intervenors for
any evidence that might contradict management’s assertions related to recoverability of recorded assets.
• We inquired of management about property, plant, and equipment that may be abandoned. We inspected minutes of meetings
of the board of directors and regulatory orders and other filings with regulatory commissions to identify evidence that may
contradict management’s assertion regarding probability of an abandonment.
• We obtained an analysis from management regarding probability of recovery for regulatory assets or refund or future reduction
in rates for regulatory liabilities not yet addressed in a regulatory order to assess management’s assertion that amounts are
probable of recovery or a future reduction in rates.
• We evaluated the impact of the February 26, 2020 sale transaction on the carrying value of the Company’s utility property,
plant, and equipment as of December 31, 2019.
Impairment of the Franchise Rights Intangible Asset & the Columbia of Massachusetts Reporting Unit Goodwill - Refer to
Note 6 to the financial statements
Critical Audit Matter Description
The Company assessed the changes in circumstances that occurred during the fourth quarter to determine whether it was more
likely than not that the fair values of the long-lived assets (including the franchise rights intangible asset) and goodwill of Columbia
of Massachusetts (CMA), a wholly-owned subsidiary of the Company, were below their carrying amount. The totality of several
factors led to the Company concluding that it was more likely than not that the fair value of the CMA reporting unit and the value
of CMA’s long-lived assets were below their carrying values. These factors included: (1) increased Massachusetts Department of
Public Utilities (DPU) regulatory enforcement activity related to CMA, including (i) an order imposing work restrictions on CMA,
(ii) two orders opening public investigations into CMA related to the Greater Lawrence Incident and restoration efforts following
the incident, and (iii) an order defining the scope of the DPU’s investigation into the preparation and response of CMA related to
the incident; (2) increased uncertainty as to the ability of CMA to execute its growth strategy, including utility infrastructure
52
Table of Contents
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (continued)
NISOURCE INC.
REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM
investments, and CMA’s ability to obtain timely regulatory outcomes with reasonable rates of return; (3) further damage to CMA’s
reputation; and (4) the potential sale of the Company's business in Massachusetts.
The Company performed a long-lived asset impairment test as of December 31, 2019 in which it compared the book value of the
CMA asset group to its undiscounted future cash flows and determined that the carrying value of the asset group was not recoverable.
The Company estimated the fair value of the CMA asset group using a weighting of income and market approaches and determined
that the fair value was less than the carrying value. The resulting impairment loss was allocated to reduce the recorded franchise
rights intangible asset to its fair value of zero, which resulted in an impairment charge totaling $209.7 million for the year ended
December 31, 2019. The Company also performed a goodwill impairment test for the CMA reporting unit as of December 31,
2019. As part of this test, the Company estimated CMA’s fair value based on a weighting of income and market approaches. This
impairment analysis indicated that the fair value of the CMA reporting unit was below its carrying value and, as a result, the
Company recognized a goodwill impairment charge totaling $204.8 million.
We identified the impairment of the franchise rights intangible asset and the CMA reporting unit goodwill as a critical audit matter
as there was a high degree of auditor judgment and subjectivity in applying procedures relating to the allocation of impairment to
CMA’s long-lived assets and the fair value measurement of the reporting unit. This was driven by significant management judgment
when determining fair value, including (1) the weightings of the fair value approaches, (2) the future cash flows used in the
impairment tests, and (3) other inputs used in the valuation including comparable company multiples, discount rates, and return
on equity. In addition, the audit effort involved the use of fair value specialists to assist in performing audit procedures over these
assumptions and evaluating the audit evidence obtained.
How the Critical Audit Matter Was Addressed in the Audit
Our audit procedures related to the impairment of CMA’s franchise rights intangible asset and CMA reporting unit goodwill
included the following, among others:
• We tested the effectiveness of management’s controls over the impairments, including (1) validation of the assumptions included
in the impairment analysis for both the franchise rights intangible asset and goodwill, (2) the evaluation of the methodology
used in determining the magnitude of impairment charges as of December 31, 2019, and (3) the verification of the completeness
and accuracy of the journal entry made to record the impairments and the related disclosures.
• We evaluated the inputs used in the franchise rights intangible asset and goodwill impairment tests, including cash flow
projections, scenario analysis, discount rates, return on equity assumptions, and comparable company multiples.
• We compared the undiscounted cash flows used in the franchise rights intangible asset impairment test to the carrying value
of the asset group to evaluate whether an impairment existed at December 31, 2019.
• With the assistance of our fair value specialists, we evaluated the reasonableness of the calculated amount of fair value of the
franchise rights intangible asset.
• We evaluated the allocation of impairment to the franchise rights intangible asset.
• We evaluated the relative weightings of the income and market approaches used to estimate fair value for the purposes of the
goodwill impairment test.
• We evaluated the reasonableness of the fair value calculated under the combination of income and market approaches by
comparing it to the fair value used in the May 1, 2019 goodwill impairment test.
• We evaluated the Company’s disclosures related to the impairment charges.
/s/ DELOITTE & TOUCHE LLP
Columbus, Ohio
February 27, 2020
We have served as the Company's auditor since 2002.
53
Table of Contents
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (continued)
NISOURCE INC.
STATEMENTS OF CONSOLIDATED INCOME (LOSS)
Year Ended December 31, (in millions, except per share amounts)
Operating Revenues
Customer revenues
Other revenues
Total Operating Revenues
Operating Expenses
Cost of sales (excluding depreciation and amortization)
Operation and maintenance
Depreciation and amortization
Impairment of goodwill and other intangible assets
Loss on sale of fixed assets and impairments, net
Other taxes
Total Operating Expenses
Operating Income
Other Income (Deductions)
Interest expense, net
Other, net
Loss on early extinguishment of long-term debt
Total Other Deductions, Net
Income (Loss) before Income Taxes
Income Taxes
Net Income (Loss)
Preferred dividends
Net Income (Loss) Available to Common Shareholders
Earnings (Loss) Per Share
Basic Earnings (Loss) Per Share
Diluted Earnings (Loss) Per Share
Basic Average Common Shares Outstanding
Diluted Average Common Shares
2019
2018
2017
$
5,053.4
$
4,991.1
$
155.5
5,208.9
1,534.8
1,354.7
717.4
414.5
—
296.8
4,318.2
890.7
(378.9)
(5.2)
—
(384.1)
506.6
123.5
383.1
(55.1)
328.0
123.4
5,114.5
1,761.3
2,352.9
599.6
—
1.2
274.8
4,989.8
124.7
(353.3)
43.5
(45.5)
(355.3)
(230.6)
(180.0)
(50.6)
(15.0)
(65.6)
$
$
$
$
0.88
0.87
374.6
376.0
(0.18) $
(0.18) $
356.5
356.5
4,730.2
144.4
4,874.6
1,518.7
1,601.7
570.3
—
5.5
257.2
3,953.4
921.2
(353.2)
(13.5)
(111.5)
(478.2)
443.0
314.5
128.5
—
128.5
0.39
0.39
329.4
330.8
The accompanying Notes to Consolidated Financial Statements are an integral part of these statements.
54
Table of Contents
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (continued)
NISOURCE INC.
STATEMENTS OF CONSOLIDATED COMPREHENSIVE INCOME (LOSS)
Year Ended December 31, (in millions, net of taxes)
Net Income (Loss)
Other comprehensive income (loss):
2019
2018
2017
$
383.1
$
(50.6) $
128.5
Total other comprehensive income (loss)
Net unrealized gain (loss) on available-for-sale securities(1)
Net unrealized gain (loss) on cash flow hedges(2)
Unrecognized pension and OPEB benefit (costs)(3)
0.8
(22.5)
3.4
(18.3)
Total Comprehensive Income (Loss)
110.2
(1) Net unrealized gain (loss) on available-for-sale securities, net of $1.5 million tax expense, $0.6 million tax benefit and $0.4 million tax expense in 2019, 2018
and 2017, respectively.
(2) Net unrealized gain (loss) on derivatives qualifying as cash flow hedges, net of $21.2 million tax benefit, $7.5 million tax expense and $13.9 million tax benefit
in 2019, 2018 and 2017, respectively.
(3) Unrecognized pension and OPEB benefit (costs), net of $1.6 million tax expense, $1.5 million tax benefit and $2.1 million tax expense in 2019, 2018 and 2017,
respectively.
(2.6)
22.7
(4.4)
15.7
(34.9) $
5.7
(64.2)
3.1
(55.4)
327.7
$
$
The accompanying Notes to Consolidated Financial Statements are an integral part of these statements.
55
Table of Contents
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (continued)
NISOURCE INC.
CONSOLIDATED BALANCE SHEETS
(in millions)
ASSETS
Property, Plant and Equipment
Utility plant
Accumulated depreciation and amortization
Net utility plant
Other property, at cost, less accumulated depreciation
Net Property, Plant and Equipment
Investments and Other Assets
Unconsolidated affiliates
Other investments
Total Investments and Other Assets
Current Assets
Cash and cash equivalents
Restricted cash
Accounts receivable (less reserve of $19.2 and $21.1, respectively)
Gas inventory
Materials and supplies, at average cost
Electric production fuel, at average cost
Exchange gas receivable
Regulatory assets
Prepayments and other
Total Current Assets
Other Assets
Regulatory assets
Goodwill
Intangible assets, net
Deferred charges and other
Total Other Assets
Total Assets
December 31,
2019
December 31,
2018
$
$
24,502.6
(7,609.3)
16,893.3
18.9
22,780.8
(7,257.9)
15,522.9
19.6
16,912.2
15,542.5
1.3
228.9
230.2
139.3
9.1
856.9
250.9
120.2
53.6
48.5
225.7
149.7
2.1
204.0
206.1
112.8
8.3
1,058.5
286.8
101.0
34.7
88.4
235.4
129.5
1,853.9
2,055.4
2,013.9
1,485.9
—
163.7
3,663.5
2,002.1
1,690.7
220.7
86.5
4,000.0
$
22,659.8
$
21,804.0
The accompanying Notes to Consolidated Financial Statements are an integral part of these statements.
56
Table of Contents
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (continued)
NISOURCE INC.
CONSOLIDATED BALANCE SHEETS
(in millions, except share amounts)
CAPITALIZATION AND LIABILITIES
Capitalization
Stockholders’ Equity
Common stock - $0.01 par value, 600,000,000 shares authorized; 382,135,680 and
372,363,656 shares outstanding, respectively
Preferred stock - $0.01 par value, 20,000,000 shares authorized; 440,000 and 420,000
shares outstanding, respectively
Treasury stock
Additional paid-in capital
Retained deficit
Accumulated other comprehensive loss
Total Stockholders’ Equity
Long-term debt, excluding amounts due within one year
Total Capitalization
Current Liabilities
Current portion of long-term debt
Short-term borrowings
Accounts payable
Customer deposits and credits
Taxes accrued
Interest accrued
Exchange gas payable
Regulatory liabilities
Legal and environmental
Accrued compensation and employee benefits
Claims accrued
Other accruals
Total Current Liabilities
Other Liabilities
Risk management liabilities
Deferred income taxes
Deferred investment tax credits
Accrued insurance liabilities
Accrued liability for postretirement and postemployment benefits
Regulatory liabilities
Asset retirement obligations
Other noncurrent liabilities
Total Other Liabilities
December 31,
2019
December 31,
2018
$
3.8
$
3.8
880.0
(99.9)
6,666.2
(1,370.8)
(92.6)
5,986.7
7,856.2
13,842.9
13.4
1,773.2
666.0
256.4
231.6
99.4
59.7
160.2
20.1
156.3
165.4
144.1
880.0
(99.9)
6,403.5
(1,399.3)
(37.2)
5,750.9
7,105.4
12,856.3
50.0
1,977.2
883.8
238.9
222.7
90.7
85.5
140.9
18.9
149.7
114.7
63.8
3,745.8
4,036.8
134.0
1,485.3
9.7
81.5
373.2
2,352.0
416.9
218.5
5,071.1
46.7
1,330.5
11.2
84.4
389.1
2,519.1
352.0
177.9
4,910.9
Commitments and Contingencies (Refer to Note 19, "Other Commitments and
Contingencies")
Total Capitalization and Liabilities
—
—
$
22,659.8
$
21,804.0
The accompanying Notes to Consolidated Financial Statements are an integral part of these statements.
57
Table of Contents
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (continued)
NISOURCE INC.
STATEMENTS OF CONSOLIDATED CASH FLOWS
Year Ended December 31, (in millions)
Operating Activities
Net Income (Loss)
Adjustments to Reconcile Net Income (Loss) to Net Cash from Operating Activities:
Loss on early extinguishment of debt
Depreciation and amortization
Deferred income taxes and investment tax credits
Stock compensation expense and 401(k) profit sharing contribution
Impairment of goodwill and other intangible assets
Amortization of discount/premium on debt
AFUDC equity
Other adjustments
Changes in Assets and Liabilities:
Accounts receivable
Inventories
Accounts payable
Customer deposits and credits
Taxes accrued
Interest accrued
Exchange gas receivable/payable
Other accruals
Prepayments and other current assets
Regulatory assets/liabilities
Postretirement and postemployment benefits
Deferred charges and other noncurrent assets
Other noncurrent liabilities
Net Cash Flows from Operating Activities
Investing Activities
Capital expenditures
Cost of removal
Purchases of available-for-sale securities
Sales of available-for-sale securities
Other investing activities
Net Cash Flows used for Investing Activities
Financing Activities
Issuance of long-term debt
Repayments of long-term debt and finance lease obligations
Issuance of short-term debt (maturity > 90 days)
Repayment of short-term debt (maturity > 90 days)
Change in short-term borrowings, net (maturity
Issuance of common stock, net of issuance costs
Issuance of preferred stock, net of issuance costs
Equity costs, premiums and other debt related costs
Acquisition of treasury stock
Dividends paid - common stock
Dividends paid - preferred stock
90 days)
Net Cash Flows from Financing Activities
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
2019
2018
2017
$
383.1
$
(50.6) $
—
717.4
118.2
25.9
414.5
8.2
(8.0)
(0.9)
187.8
(2.0)
(299.9)
16.9
7.3
8.8
55.5
105.3
(33.6)
(85.6)
(21.1)
(76.1)
61.6
1,583.3
(1,802.4)
(113.2)
(140.4)
132.1
1.5
(1,922.4)
750.0
(51.6)
600.0
(700.0)
(104.0)
244.4
—
(17.8)
—
(298.5)
(56.1)
366.4
27.3
121.1
148.4
$
45.5
599.6
(188.2)
28.6
—
7.5
(14.2)
1.7
(186.2)
41.4
268.4
(25.4)
20.2
(21.7)
(21.5)
43.5
(14.5)
(53.2)
58.2
3.8
(2.8)
540.1
(1,818.2)
(104.3)
(90.0)
82.3
4.1
(1,926.1)
350.0
(1,046.1)
950.0
—
(178.5)
848.2
880.0
(46.0)
(4.0)
(273.3)
(11.6)
1,468.7
82.7
38.4
121.1
$
$
128.5
111.5
570.3
306.7
40.1
—
7.4
(12.6)
6.6
(52.3)
19.0
49.0
(2.5)
10.2
(33.9)
(64.5)
31.8
(13.3)
57.5
(380.9)
(2.0)
(34.4)
742.2
(1,695.8)
(109.0)
(168.4)
163.1
1.6
(1,808.5)
3,250.0
(1,855.0)
—
—
(282.4)
336.7
—
(144.3)
(7.2)
(229.1)
—
1,068.7
2.4
36.0
38.4
The accompanying Notes to Consolidated Financial Statements are an integral part of these statements.
58
Table of Contents
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (continued)
NISOURCE INC.
STATEMENTS OF CONSOLIDATED STOCKHOLDERS’ EQUITY
(in millions)
Balance as of January 1, 2017
Comprehensive Income:
Net Income
Other comprehensive loss, net of tax
Common stock dividends ($0.70 per share)
Treasury stock acquired
Stock issuances:
Employee stock purchase plan
Long-term incentive plan
401(k) and profit sharing
Dividend reinvestment plan
ATM Program
Balance as of December 31, 2017
$
Comprehensive Loss:
Net Loss
Other comprehensive income, net of tax
Dividends
Common stock ($0.78 per share)
Preferred stock ($28.88 per share)
Treasury stock acquired
Cumulative effect of change in accounting principle
Stock issuances:
Common stock - private placement
Preferred stock
Employee stock purchase plan
Long-term incentive plan
401(k) and profit sharing
ATM Program
Balance as of December 31, 2018
$
Comprehensive Income:
Net Income
Other comprehensive loss, net of tax
Dividends:
Common stock ($0.80 per share)
Preferred stock (See Note 12)
Stock issuances:
Employee stock purchase plan
Long-term incentive plan
401(k) and profit sharing
ATM program
Common
Stock
Preferred
Stock(1)
Treasury
Stock
Additional
Paid-In
Capital
Retained
Deficit
Accumulated
Other
Comprehensive
Loss
Total
$
3.3
$
— $
(88.7) $
5,153.9
$
(972.2) $
(25.1) $ 4,071.2
—
—
—
—
—
—
—
—
0.1
3.4
—
—
—
—
—
—
0.3
—
—
—
—
0.1
3.8
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
(7.2)
—
—
—
—
—
—
—
—
—
5.0
14.9
34.3
6.4
314.6
128.5
—
(229.4)
—
—
—
—
—
—
—
(18.3)
—
—
—
—
—
—
—
128.5
(18.3)
(229.4)
(7.2)
5.0
14.9
34.3
6.4
314.7
$
— $
(95.9) $
5,529.1
$ (1,073.1) $
(43.4) $ 4,320.1
—
—
—
—
—
—
—
880.0
—
—
—
—
—
—
—
—
(4.0)
—
—
—
—
—
—
—
—
—
—
—
—
—
599.3
—
5.5
15.4
21.8
232.4
(50.6)
—
(273.5)
(11.6)
—
9.5
—
—
—
—
—
—
—
15.7
—
—
—
(9.5)
—
—
—
—
—
—
(50.6)
15.7
(273.5)
(11.6)
(4.0)
—
599.6
880.0
5.5
15.4
21.8
232.5
$
880.0
$
(99.9) $
6,403.5
$ (1,399.3) $
(37.2) $ 5,750.9
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
5.6
10.4
17.6
229.1
383.1
—
(298.5)
(56.1)
—
—
—
—
—
(55.4)
—
—
—
—
—
—
383.1
(55.4)
(298.5)
(56.1)
5.6
10.4
17.6
229.1
Balance as of December 31, 2019
(92.6) $ 5,986.7
(1)Series A and Series B shares have an aggregate liquidation preference of $400M and $500M, respectively. See Note 12, "Equity" for additional information.
$ (1,370.8) $
(99.9) $
6,666.2
880.0
3.8
$
$
$
The accompanying Notes to Consolidated Financial Statements are an integral part of these statements.
59
Table of Contents
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (continued)
NISOURCE INC.
STATEMENTS OF CONSOLIDATED STOCKHOLDERS’ EQUITY
(in thousands)
Balance as of January 1, 2017
Treasury stock acquired
Issued:
Employee stock purchase plan
Long-term incentive plan
401(k) and profit sharing plan
Dividend reinvestment plan
ATM program
Balance as of December 31, 2017
Treasury stock acquired
Issued:
Common stock - private placement
Preferred stock
Employee stock purchase plan
Long-term incentive plan
401(k) and profit sharing plan
ATM Program
Balance as of December 31, 2018
Issued:
Preferred stock(1)
Employee stock purchase plan
Long-term incentive plan
401(k) and profit sharing plan
ATM program
Balance as of December 31, 2019
Preferred
Shares
Common
Shares
Treasury
Outstanding
—
—
—
—
—
—
—
—
—
—
420
—
—
—
—
420
20
—
—
—
—
440
326,664
—
207
351
1,396
264
11,931
340,813
—
24,964
—
223
561
882
8,883
376,326
—
201
518
631
8,423
386,099
(3,504)
(293)
323,160
(293)
—
—
—
—
—
(3,797)
(166)
—
—
—
—
—
—
(3,963)
—
—
—
—
—
(3,963)
207
351
1,396
264
11,931
337,016
(166)
24,964
—
223
561
882
8,883
372,363
—
201
518
631
8,423
382,136
(1)See Note 12, "Equity," for additional information.
Accompanying Notes to Consolidated Financial Statements are an integral part of these statements.
60
Table of Contents
NISOURCE INC.
Notes to Consolidated Financial Statements
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (continued)
1.
Nature of Operations and Summary of Significant Accounting Policies
A. Company Structure and Principles of Consolidation. We are an energy holding company incorporated in Delaware and
headquartered in Merrillville, Indiana. Our subsidiaries are fully regulated natural gas and electric utility companies serving
approximately 4.0 million customers in seven states. We generate substantially all of our operating income through these rate-
regulated businesses. The consolidated financial statements include the accounts of us and our majority-owned subsidiaries after
the elimination of all intercompany accounts and transactions.
On February 26, 2020, NiSource and Columbia of Massachusetts entered into the Asset Purchase Agreement with Eversource, a
Massachusetts voluntary association. Upon the terms and subject to the conditions set forth in the Asset Purchase Agreement,
NiSource and Columbia of Massachusetts agreed to sell to Eversource, with certain additions and exceptions, (1) substantially all
of the assets of Columbia of Massachusetts and (2) all of the assets held by any of Columbia of Massachusetts’ affiliates that
primarily relate to the business of storing, distributing or transporting natural gas to residential, commercial and industrial customers
in Massachusetts, as conducted by Columbia of Massachusetts, and Eversource agreed to assume certain liabilities of Columbia
of Massachusetts and its affiliates. For additional information, see Note 26, “Subsequent Event.”
B. Use of Estimates. The preparation of financial statements in conformity with GAAP requires management to make
estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities
at the date of the financial statements, and the reported amounts of revenues and expenses during the reporting period. Actual
results could differ from those estimates.
C. Cash, Cash Equivalents and Restricted Cash. We consider all highly liquid investments with original maturities of
three months or less to be cash equivalents. We report amounts deposited in brokerage accounts for margin requirements as restricted
cash. In addition, we have amounts deposited in trust to satisfy requirements for the provision of various property, liability, workers
compensation, and long-term disability insurance, which is classified as restricted cash on the Consolidated Balance Sheets and
disclosed with cash and cash equivalents on the Statements of Consolidated Cash Flows.
D. Accounts Receivable and Unbilled Revenue. Accounts receivable on the Consolidated Balance Sheets includes both
billed and unbilled amounts. Unbilled amounts of accounts receivable relate to a portion of a customer’s consumption of gas or
electricity from the last cycle billing date through the last day of the month (balance sheet date). Factors taken into consideration
when estimating unbilled revenue include historical usage, customer rates and weather. Accounts receivable fluctuates from year
to year depending in large part on weather impacts and price volatility. Our accounts receivable on the Consolidated Balance Sheets
include unbilled revenue, less reserves, in the amounts of $350.5 million and $324.2 million as of December 31, 2019 and 2018,
respectively. The reserve for uncollectible receivables is our best estimate of the amount of probable credit losses in the existing
accounts receivable. We determined the reserve based on historical experience and in consideration of current market conditions.
Account balances are charged against the allowance when it is anticipated the receivable will not be recovered. Refer to Note 3,
"Revenue Recognition," for additional information on customer-related accounts receivable.
E. Investments in Debt Securities. Our investments in debt securities are carried at fair value and are designated as available-
for-sale. These investments are included within “Other investments” on the Consolidated Balance Sheets. Unrealized gains and
losses, net of deferred income taxes, are recorded to accumulated other comprehensive income or loss. These investments are
monitored for other than temporary declines in market value. Realized gains and losses and permanent impairments are reflected
in the Statements of Consolidated Income (Loss). No material impairment charges were recorded for the years ended December 31,
2019, 2018 or 2017. Refer to Note 17, "Fair Value," for additional information.
F. Basis of Accounting for Rate-Regulated Subsidiaries. Rate-regulated subsidiaries account for and report assets and
liabilities consistent with the economic effect of the way in which regulators establish rates, if the rates established are designed
to recover the costs of providing the regulated service and it is probable that such rates can be charged and collected. Certain
expenses and credits subject to utility regulation or rate determination normally reflected in income are deferred on the Consolidated
Balance Sheets and are later recognized in income as the related amounts are included in customer rates and recovered from or
refunded to customers.
In the event that regulation significantly changes the opportunity for us to recover our costs in the future, all or a portion of our
regulated operations may no longer meet the criteria for regulatory accounting. In such an event, a write-down of all or a portion
of our existing regulatory assets and liabilities could result. If transition cost recovery was approved by the appropriate regulatory
bodies that would meet the requirements under GAAP for continued accounting as regulatory assets and liabilities during such
recovery period, the regulatory assets and liabilities would be reported at the recoverable amounts. If unable to continue to apply
61
Table of Contents
NISOURCE INC.
Notes to Consolidated Financial Statements
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (continued)
the provisions of regulatory accounting, we would be required to apply the provisions of ASC 980-20, Discontinuation of Rate-
Regulated Accounting. In management’s opinion, our regulated subsidiaries will be subject to regulatory accounting for the
foreseeable future. Refer to Note 8, "Regulatory Matters," for additional information.
G. Plant and Other Property and Related Depreciation and Maintenance. Property, plant and equipment (principally
utility plant) is stated at cost. The rate-regulated subsidiaries record depreciation using composite rates on a straight-line basis over
the remaining service lives of the electric, gas and common properties as approved by the appropriate regulators.
Non-utility property is generally depreciated on a straight-line basis over the life of the associated asset. Refer to Note 5, "Property,
Plant and Equipment," for additional information related to depreciation expense.
For rate-regulated companies, AFUDC is capitalized on all classes of property except organization costs, land, autos, office
equipment, tools and other general property purchases. The allowance is applied to construction costs for that period of time
between the date of the expenditure and the date on which such project is placed in service. Our pre-tax rate for AFUDC was 3.0%
in 2019, 3.5% in 2018 and 4.0% in 2017.
Generally, our subsidiaries follow the practice of charging maintenance and repairs, including the cost of removal of minor items
of property, to expense as incurred. When our subsidiaries retire regulated property, plant and equipment, original cost plus the
cost of retirement, less salvage value, is charged to accumulated depreciation. However, when it becomes probable a regulated
asset will be retired substantially in advance of its original expected useful life or is abandoned, the cost of the asset and the
corresponding accumulated depreciation is recognized as a separate asset. If the asset is still in operation, the net amount is classified
as "Other property, at cost, less accumulated depreciation" on the Consolidated Balance Sheets. If the asset is no longer operating,
the net amount is classified in "Regulatory assets" on the Consolidated Balance Sheets. If we are able to recover a full return of
and on investment, the carrying value of the asset is based on historical cost. If we are not able to recover a full return on investment,
a loss on impairment is recognized to the extent the net book value of the asset exceeds the present value of future revenues
discounted at the incremental borrowing rate.
When our subsidiaries sell entire regulated operating units, or retire or sell nonregulated properties, the original cost and accumulated
depreciation and amortization balances are removed from "Property, Plant and Equipment" on the Consolidated Balance Sheets.
Any gain or loss is recorded in earnings, unless otherwise required by the applicable regulatory body. Refer to Note 5, "Property,
Plant and Equipment," for further information.
External and internal costs associated with computer software developed for internal use are capitalized. Capitalization of such
costs commences upon the completion of the preliminary stage of each project. Once the installed software is ready for its intended
use, such capitalized costs are amortized on a straight-line basis generally over a period of five years, except for certain significant
enterprise-wide technology investments which are amortized over a ten-year period.
External and internal up-front implementation costs associated with cloud computing arrangements that are service contracts are
deferred on the Consolidated Balance Sheets. Once the installed software is ready for its intended use, such deferred costs are
amortized on a straight-line basis to "Operation and maintenance," over the minimum term of the contract plus contractually-
provided renewal periods that are reasonable expected to be exercised -- generally up to a maximum of five years.
H. Goodwill and Other Intangible Assets. Substantially all of our goodwill relates to the excess of cost over the fair value
of the net assets acquired in the Columbia acquisition on November 1, 2000. We test our goodwill for impairment annually as of
May 1, or more frequently if events and circumstances indicate that goodwill might be impaired. Fair value of our reporting units
is determined using a combination of income and market approaches.
We had other intangible assets consisting primarily of franchise rights apart from goodwill that were identified as part of the
purchase price allocations associated with the acquisition of Columbia of Massachusetts, which were being amortized on a straight-
line basis over forty years from the date of acquisition.
During the fourth quarter of 2019, we impaired goodwill and intangible assets related to Columbia of Massachusetts. See Note
6, "Goodwill and Other Intangible Assets," for additional information.
I. Accounts Receivable Transfer Program. Certain of our subsidiaries have agreements with third parties to transfer certain
accounts receivable without recourse. These transfers of accounts receivable are accounted for as secured borrowings. The entire
gross receivables balance remains on the December 31, 2019 and 2018 Consolidated Balance Sheets and short-term debt is recorded
62
Table of Contents
NISOURCE INC.
Notes to Consolidated Financial Statements
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (continued)
in the amount of proceeds received from the transferees involved in the transactions. Refer to Note 18, "Transfers of Financial
Assets," for further information.
J. Gas Cost and Fuel Adjustment Clause. Our regulated subsidiaries defer most differences between gas and fuel purchase
costs and the recovery of such costs in revenues, and adjust future billings for such deferrals on a basis consistent with applicable
state-approved tariff provisions. These deferred balances are recorded as "Regulatory assets" or "Regulatory liabilities," as
appropriate, on the Consolidated Balance Sheets. Refer to Note 8, "Regulatory Matters," for additional information.
K. Inventory. Both the LIFO inventory methodology and the weighted average cost methodology are used to value natural
gas in storage, as approved by regulators for all of our regulated subsidiaries. Inventory valued using LIFO was $47.2 million and
$47.5 million at December 31, 2019 and 2018, respectively. Based on the average cost of gas using the LIFO method, the estimated
replacement cost of gas in storage was less than the stated LIFO cost by $25.5 million and $12.2 million at December 31, 2019
and 2018, respectively. Gas inventory valued using the weighted average cost methodology was $203.7 million at December 31,
2019 and $239.3 million at December 31, 2018.
Electric production fuel is valued using the weighted average cost inventory methodology, as approved by NIPSCO's regulator.
Materials and supplies are valued using the weighted average cost inventory methodology.
L. Accounting for Exchange and Balancing Arrangements of Natural Gas. Our Gas Distribution Operations segment
enters into balancing and exchange arrangements of natural gas as part of its operations and off-system sales programs. We record
a receivable or payable for any of our respective cumulative gas imbalances, as well as for any gas inventory borrowed or lent
under a Gas Distribution Operations exchange agreement. Exchange gas is valued based on individual regulatory jurisdiction
requirements (for example, historical spot rate, spot at the beginning of the month). These receivables and payables are recorded
as “Exchange gas receivable” or “Exchange gas payable” on our Consolidated Balance Sheets, as appropriate.
M. Accounting for Risk Management Activities. We account for our derivatives and hedging activities in accordance
with ASC 815. We recognize all derivatives as either assets or liabilities on the Consolidated Balance Sheets at fair value, unless
such contracts are exempted as a normal purchase normal sale under the provisions of the standard. The accounting for changes
in the fair value of a derivative depends on the intended use of the derivative and resulting designation.
We have elected not to net fair value amounts for any of our derivative instruments or the fair value amounts recognized for the
right to receive cash collateral or obligation to pay cash collateral arising from those derivative instruments recognized at fair
value, which are executed with the same counterparty under a master netting arrangement. See Note 9, "Risk Management
Activities," for additional information.
N. Income Taxes and Investment Tax Credits. We record income taxes to recognize full interperiod tax allocations. Under
the asset and liability method, deferred income taxes are provided for the tax consequences of temporary differences by applying
enacted statutory tax rates applicable to future years to differences between the financial statement carrying amount and the tax
basis of existing assets and liabilities. Investment tax credits associated with regulated operations are deferred and amortized as a
reduction to income tax expense over the estimated useful lives of the related properties.
To the extent certain deferred income taxes of the regulated companies are recoverable or payable through future rates, regulatory
assets and liabilities have been established. Regulatory assets for income taxes are primarily attributable to property-related tax
timing differences for which deferred taxes had not been provided in the past, when regulators did not recognize such taxes as
costs in the rate-making process. Regulatory liabilities for income taxes are primarily attributable to the regulated companies’
obligation to refund to ratepayers deferred income taxes provided at rates higher than the current Federal income tax rate. Such
property-related amounts are credited to ratepayers using either the average rate assumption method or the reverse South Georgia
method. Non property-related amounts are credited to ratepayers consistent with state utility commission direction.
Pursuant to the Internal Revenue Code and relevant state taxing authorities, we and our subsidiaries file consolidated income tax
returns for federal and certain state jurisdictions. We and our subsidiaries are parties to a tax sharing agreement. Income taxes
recorded by each party represent amounts that would be owed had the party been separately subject to tax.
O. Environmental Expenditures. We accrue for costs associated with environmental remediation obligations when the
incurrence of such costs is probable and the amounts can be reasonably estimated, regardless of when the expenditures are actually
made. The undiscounted estimated future expenditures are based on currently enacted laws and regulations, existing technology
and estimated site-specific costs where assumptions may be made about the nature and extent of site contamination, the extent of
63
Table of Contents
NISOURCE INC.
Notes to Consolidated Financial Statements
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (continued)
cleanup efforts, costs of alternative cleanup methods and other variables. The liability is adjusted as further information is discovered
or circumstances change. The accruals for estimated environmental expenditures are recorded on the Consolidated Balance Sheets
in “Legal and environmental” for short-term portions of these liabilities and “Other noncurrent liabilities” for the respective long-
term portions of these liabilities. Rate-regulated subsidiaries applying regulatory accounting establish regulatory assets on the
Consolidated Balance Sheets to the extent that future recovery of environmental remediation costs is probable through the regulatory
process. Refer to Note 19, "Other Commitments and Contingencies," for further information.
P. Excise Taxes. As an agent for some state and local governments, we invoice and collect certain excise taxes levied by state
and local governments on customers and record these amounts as liabilities payable to the applicable taxing jurisdiction. Such
balances are presented within "Other accruals" on the Consolidated Balance Sheets. These types of taxes collected from customers,
comprised largely of sales taxes, are presented on a net basis affecting neither revenues nor cost of sales. We account for excise
taxes for which we are liable by recording a liability for the expected tax with a corresponding charge to “Other taxes” expense
on the Statements of Consolidated Income (Loss).
Q. Accrued Insurance Liabilities. We accrue for insurance costs related to workers compensation, automobile, property,
general and employment practices liabilities based on the most probable value of each claim. In general, claim values are determined
by professional, licensed loss adjusters who consider the facts of the claim, anticipated indemnification and legal expenses, and
respective state rules. Claims are reviewed by us at least quarterly and an adjustment is made to the accrual based on the most
current information. Refer to Note 19-E "Other Matters" for further information on accrued insurance liabilities related to the
Greater Lawrence Incident.
2.
Recent Accounting Pronouncements
Recently Issued Accounting Pronouncements
We are currently evaluating the impact of certain ASUs on our Consolidated Financial Statements or Notes to Consolidated Financial
Statements, which are described below:
Standard
ASU 2018-14,
Compensation—
Retirement Benefits—
Defined Benefit Plans
—General (Subtopic
715-20): Disclosure
Framework—Changes
to the Disclosure
Requirements for
Defined Benefit Plans
ASU 2019-12,
Income Taxes (Topic
740): Simplifying the
Accounting for
Income Taxes
Description
The pronouncement modifies the
disclosure requirements for defined
benefit pension or other
postretirement benefit plans. The
guidance removes disclosures that
are no longer considered cost
beneficial, clarifies the specific
requirements of disclosures and
adds disclosure requirements
identified as relevant. The
modifications affect annual period
disclosures and must be applied on
a retrospective basis to all periods
presented.
This pronouncement simplifies the
accounting for income taxes by
eliminating certain exceptions to
the general principles in ASC 740,
income taxes. It also improves
consistency of application for other
areas of the guidance by clarifying
and amending existing guidance.
Effective Date
Annual periods ending
after December 15,
2020. Early adoption
is permitted.
Effect on the financial statements or
other significant matters
We are currently evaluating the effects
of this pronouncement on our Notes to
Consolidated Financial Statements. We
expect to adopt this ASU on its
effective date.
Annual periods
beginning after
December 15, 2020.
Early adoption is
permitted.
We are currently evaluating the effects
of this pronouncement on our
Consolidated Financial Statements and
Notes to Consolidated Financial
Statements. We tentatively expect to
adopt this ASU on its effective date.
64
Table of Contents
NISOURCE INC.
Notes to Consolidated Financial Statements
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (continued)
Recently Adopted Accounting Pronouncements
Standard
ASU 2019-01, Leases
(Topic 842):
Codification
Improvements
ASU 2018-11, Leases
(Topic 842): Targeted
Improvements
ASU 2018-01, Leases
(Topic 842): Land
Easement Practical
Expedient for
Transition to Topic 842
ASU 2016-02, Leases
(Topic 842)
ASU 2019-04,
Codification
Improvements to Topic
326, Financial
Instruments-Credit
Losses, Topic 815,
Derivatives and
Hedging, and Topic
825, Financial
Instruments
ASU 2016-13,
Financial Instruments-
Credit Losses (Topic
326)
See Note 16, "Leases," for our discussion of the effects of implementing these standards.
Adoption
In June 2016, the FASB issued ASU 2016-13 that revised the guidance on the impairment of most
financial assets and certain other instruments that are not measured at fair value through net income.
This ASU replaces the current "incurred loss" model with an "expected loss" model for instruments
measured at amortized cost. It also requires entities to record allowances for available-for-sale
securities rather than impair the carrying amount of the securities. Subsequent improvements to the
estimated credit losses of available-for-sale securities will be recognized immediately in earnings
instead of over time as they are under historic guidance.
We adopted this ASU effective January 1, 2020, using a modified retrospective method. Adoption of
this standard did not have a material impact on our Consolidated Financial Statements. No material
adjustments were made to January 1, 2020 opening balances as a result of adoption. For our
investments that are classified as available for sale debt securities, we will recognize impairment
using an allowance approach instead of an 'other than temporary' impairment (OTTI) model. Since
we do not have amounts previously recognized in other comprehensive income related to previous
OTTI charges, provisions of this ASU are adopted prospectively. In regards to our recorded balances
of trade receivables that fall within the scope of this ASU, the ASU did not result in any significant
modifications to our policies related to recognizing an allowance on our trade receivables. Based on
shared risk characteristics, we segregate our trade receivables into separate pools. We will apply
separate models to calculate reserves for uncollectible receivables, as well as consider factors other
than time to determine whether a credit loss exists. ASC 326 also prescribes additional presentation
and disclosure requirements. For reporting periods beginning after January 1, 2020, we will include
additional disclosures in our Notes to Consolidated Financial Statements based on qualitative and
quantitative assessment of materiality.
3.
Revenue Recognition
In 2014, the FASB issued ASU 2014-09, Revenue from Contracts with Customers (ASC 606). ASU 2014-09 outlines a single,
comprehensive model for entities to use in accounting for revenue arising from contracts with customers and supersedes most
current revenue recognition guidance. The core principle of the new standard is that an entity should recognize revenue to depict
the transfer of goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled
in exchange for those goods or services. In 2016, the FASB issued ASU 2016-08, Revenue from Contracts with Customers (ASC
606): Principal versus Agent Considerations, and ASU 2016-12, Revenue from Contracts with Customers (ASC 606): Narrow-
Scope Improvements and Practical Expedients. We adopted the provisions of ASC 606 beginning on January 1, 2018 using a
modified retrospective method, which was applied to all contracts. No material adjustments were made to January 1, 2018 opening
balances as a result of the adoption. As required under the modified retrospective method of adoption, results for reporting periods
beginning after January 1, 2018 are presented under ASC 606, while prior period amounts are not adjusted and continue to be
reported in accordance with ASC 605.
65
Table of Contents
NISOURCE INC.
Notes to Consolidated Financial Statements
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (continued)
The table below provides results for the years ended December 31, 2019 and 2018 as if it had been prepared under historic
accounting guidance. We included operating revenue information for the year ended December 31, 2017 for comparability.
Year Ended December 31, (in millions)
Operating Revenues
Gas Distribution
Gas Transportation
Electric
Other
Total Operating Revenues
2019
2018
2017
$
$
2,336.1
$
2,348.4
$
1,171.3
1,698.5
3.0
1,055.2
1,707.4
3.5
2,063.2
1,021.5
1,785.5
4.4
5,208.9
$
5,114.5
$
4,874.6
Beginning in 2018 with the adoption of ASC 606, the Statements of Consolidated Income (Loss) disaggregates “Customer
revenues” (i.e. ASC 606 Revenues) from “Other revenues,” both of which are discussed in more detail below.
Customer Revenues. Substantially all of our revenues are tariff-based, which we have concluded is within the scope of ASC 606.
Under ASC 606, the recipients of our utility service meet the definition of a customer, while the operating company tariffs represent
an agreement that meets the definition of a contract. ASC 606 defines a contract as an agreement between two or more parties, in
this case us and the customer, which creates enforceable rights and obligations. In order to be considered a contract, we have
determined that it is probable that substantially all of the consideration to which we are entitled from customers will be collected
upon satisfaction of performance obligations. We maintain common utility credit risk mitigation practices, including requiring
deposits and actively pursuing collection of past due amounts. In addition, our regulated operations utilize certain regulatory
mechanisms that facilitate recovery of bad debt costs within tariff-based rates, which provides further evidence of collectibility.
Customers in certain of our jurisdictions participate in programs that allow for a fixed payment each month regardless of usage.
Payments received that exceed the value of gas or electricity actually delivered are recorded as a liability and presented in "Customer
Deposits and Credits" on the Consolidated Balance Sheets. Amounts in this account are reduced and revenue is recorded when
customer usage begins to exceed payments received.
We have identified our performance obligations created under tariff-based sales as 1) the commodity (natural gas or electricity,
which includes generation and capacity) and 2) delivery. These commodities are sold and / or delivered to and generally consumed
by customers simultaneously, leading to satisfaction of our performance obligations over time as gas or electricity is delivered to
customers. Due to the at-will nature of utility customers, performance obligations are limited to the services requested and received
to date. Once complete, we generally maintain no additional performance obligations.
Transaction prices for each performance obligation are generally prescribed by each operating company’s respective tariff. Rates
include provisions to adjust billings for fluctuations in fuel and purchased power costs and cost of natural gas. Revenues are
adjusted for differences between actual costs subject to reconciliation and the amounts billed in current rates. Under or over
recovered revenues related to these cost recovery mechanisms are included in "Regulatory Assets" or "Regulatory Liabilities" on
the Consolidated Balance Sheets and are recovered from or returned to customers through adjustments to tariff rates. As we provide
and deliver service to customers, revenue is recognized based on the transaction price allocated to each performance obligation.
In general, revenue recognized from tariff-based sales is equivalent to the value of natural gas or electricity supplied and billed
each period, in addition to an estimate for deliveries completed during the period but not yet billed to the customer.
In addition to tariff-based sales, our Gas Distribution Operations segment enters into balancing and exchange arrangements of
natural gas as part of our operations and off-system sales programs. We have concluded that these sales are within the scope of
ASC 606. Performance obligations for these types of sales include transportation and storage of natural gas and can be satisfied
at a point in time or over a period of time, depending on the specific transaction. For those transactions that span a period of time,
we record a receivable or payable for any cumulative gas imbalances, as well as for any gas inventory borrowed or lent under a
Gas Distributions Operations exchange agreement.
Revenue Disaggregation and Reconciliation. We disaggregate revenue from contracts with customers based upon reportable
segment as well as by customer class. As our revenues are primarily earned over a period of time, and we do not earn a material
amount of revenues at a point in time, revenues are not disaggregated as such below. The Gas Distribution Operations segment
provides natural gas service and transportation for residential, commercial and industrial customers in Ohio, Pennsylvania, Virginia,
66
Table of Contents
NISOURCE INC.
Notes to Consolidated Financial Statements
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (continued)
Kentucky, Maryland, Indiana and Massachusetts. The Electric Operations segment provides electric service in 20 counties in the
northern part of Indiana.
The table below reconciles revenue disaggregation by customer class to segment revenue as well as to revenues reflected on the
Statements of Consolidated Income (Loss):
Year Ended December 31, 2019 (in millions)
Customer Revenues(1)
Gas Distribution
Operations
Electric
Operations
Corporate and
Other
Total
Residential
Commercial
Industrial
Off-system
Miscellaneous
Total Customer Revenues
Other Revenues
$
$
2,309.0
$
481.6
$
— $
771.3
245.2
77.7
52.0
486.6
607.7
—
21.5
3,455.2
$
1,597.4
$
54.5
101.0
—
—
—
0.8
0.8
—
$
Total Operating Revenues
(1) Customer revenue amounts exclude intersegment revenues. See Note 23, "Segments of Business," for discussion of intersegment revenues.
3,509.7
1,698.4
0.8
$
$
$
$
2,790.6
1,257.9
852.9
77.7
74.3
5,053.4
155.5
5,208.9
Year Ended December 31, 2018 (in millions)
Customer Revenues(1)
Gas Distribution
Operations
Electric
Operations
Corporate and
Other
Total
$
2,250.0
$
494.7
$
— $
751.9
228.0
92.4
49.7
492.7
613.6
—
17.4
—
—
—
0.7
0.7
—
$
2,744.7
1,244.6
841.6
92.4
67.8
4,991.1
123.4
5,114.5
Total Customer Revenues
Other Revenues
$
3,372.0
$
1,618.4
$
34.4
89.0
Total Operating Revenues
(1) Customer revenue amounts exclude intersegment revenues. See Note 23, "Segments of Business," for discussion of intersegment revenues.
3,406.4
1,707.4
0.7
$
$
$
$
Customer Accounts Receivable. Accounts receivable on our Consolidated Balance Sheets includes both billed and unbilled
amounts, as well as certain amounts that are not related to customer revenues. Unbilled amounts of accounts receivable relate to
a portion of a customer’s consumption of gas or electricity from the date of the last cycle billing through the last day of the month
(balance sheet date). Factors taken into consideration when estimating unbilled revenue include historical usage, customer rates
and weather. The opening and closing balances of customer receivables for the years ended December 31, 2019 and 2018 are
presented in the table below. We had no significant contract assets or liabilities during the period. Additionally, we have not incurred
any significant costs to obtain or fulfill contracts.
(in millions)
Balance as of December 31, 2018
Customer Accounts
Receivable, Billed
(less reserve)(1)
Customer Accounts
Receivable, Unbilled
(less reserve)
$
540.5
$
349.1
346.6
(2.5)
Balance as of December 31, 2019
Decrease
(1) Customer billed receivables decreased due to decreased natural gas costs and warmer weather in 2019 compared to 2018.
$
466.6
(73.9) $
Utility revenues are billed to customers monthly on a cycle basis. We generally expect that substantially all customer accounts
receivable will be collected within the month following customer billing, as this revenue consists primarily of monthly, tariff-
based billings for service and usage.
67
Residential
Commercial
Industrial
Off-system
Miscellaneous
Table of Contents
NISOURCE INC.
Notes to Consolidated Financial Statements
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (continued)
Other Revenues. As permitted by accounting principles generally accepted in the United States, regulated utilities have the ability
to earn certain types of revenue that are outside the scope of ASC 606. These revenues primarily represent revenue earned under
alternative revenue programs. Alternative revenue programs represent regulator-approved programs that allow for the adjustment
of billings and revenue for certain broad, external factors, or for additional billings if the entity achieves certain objectives, such
as a specified reduction of costs. We maintain a variety of these programs, including demand side management initiatives that
recover costs associated with the implementation of energy efficiency programs, as well as normalization programs that adjust
revenues for the effects of weather or other external factors. Additionally, we maintain certain programs with future test periods
that operate similarly to FERC formula rate programs and allow for recovery of costs incurred to replace aging infrastructure.
When the criteria to recognize alternative revenue have been met, we establish a regulatory asset and present revenue from alternative
revenue programs on the Statements of Consolidated Income (Loss) as “Other revenues.” When amounts previously recognized
under alternative revenue accounting guidance are billed, we reduce the regulatory asset and record a customer account receivable.
4.
Earnings Per Share
Basic EPS is computed by dividing net income attributable to common shareholders by the weighted-average number of shares
of common stock outstanding for the period. The weighted-average shares outstanding for diluted EPS includes the incremental
effects of the various long-term incentive compensation plans and forward agreements when the impact of such plans and agreements
would be dilutive. The calculation of diluted earnings per share for the year ended December 31, 2018 does not include any dilutive
potential common shares as we had a net loss on the Statements of Consolidated Income (Loss) for that period, and any incremental
shares would have had an anti-dilutive impact on EPS. The calculation of diluted earnings per share for the year ended December
31, 2017 excludes the impact of forward agreements, which had an anti-dilutive effect for that period. The computation of diluted
average common shares is as follows:
Year Ended December 31, (in thousands)
Denominator
Basic average common shares outstanding
Dilutive potential common shares:
Shares contingently issuable under employee stock plans
Shares restricted under stock plans
Forward agreements
Diluted Average Common Shares
2019
2018
2017
374,650
356,491
329,388
929
154
253
375,986
—
—
—
356,491
547
821
—
330,756
68
Table of Contents
NISOURCE INC.
Notes to Consolidated Financial Statements
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (continued)
5.
Property, Plant and Equipment
Our property, plant and equipment on the Consolidated Balance Sheets are classified as follows:
At December 31, (in millions)
Property, Plant and Equipment
Gas Distribution Utility(1)
Electric Utility(1)
Corporate
Construction Work in Process
Non-Utility and Other
Total Property, Plant and Equipment
Accumulated Depreciation and Amortization
Gas Distribution Utility(1)
Electric Utility(1)
Corporate
Non-Utility and Other
2019
2018
$
14,989.7
$
13,776.0
8,902.3
8,374.2
153.3
457.3
39.3
155.8
474.8
38.7
24,541.9
$
22,819.5
$
$
(3,556.0) $
(3,973.8)
(79.5)
(20.4)
(7,629.7) $
16,912.2
$
(3,373.8)
(3,809.5)
(74.6)
(19.1)
(7,277.0)
15,542.5
Total Accumulated Depreciation and Amortization
Net Property, Plant and Equipment
(1)NIPSCO’s common utility plant and associated accumulated depreciation and amortization are allocated between Gas Distribution Utility and Electric Utility
Property, Plant and Equipment.
$
$
The weighted average depreciation provisions for utility plant, as a percentage of the original cost, for the periods ended
December 31, 2019, 2018 and 2017 were as follows:
2019
2018
2017
3.4%
Electric Operations(1)
Gas Distribution Operations
2.1%
(1)Lower depreciation rate beginning in 2018 due to reduced EERM-related depreciation expense and higher depreciable base from transmission assets being
placed into service in 2018.
2.9%
2.2%
2.8%
2.5%
We recognized depreciation expense of $612.2 million, $503.4 million and $501.5 million for the years ended 2019, 2018 and
2017, respectively.
Amortization of Software Costs. We amortized $55.5 million, $54.1 million and $44.0 million in 2019, 2018 and 2017, respectively,
related to software costs. Our unamortized software balance was $169.6 million and $159.5 million at December 31, 2019 and
2018, respectively.
Amortization of Cloud Computing Costs. We amortized $1.6 million and $0.1 million in 2019 and 2018, respectively, related to
cloud computing costs. Our unamortized cloud computing balance was $14.2 million and $4.9 million at December 31, 2019 and
2018, respectively.
6.
Goodwill and Other Intangible Assets
Intangible and Other Long-Lived Assets Impairment. Our intangible assets, apart from goodwill, consist of franchise rights.
Franchise rights were identified as part of the purchase price allocations associated with the acquisition in February 1999 of
Columbia of Massachusetts. We review our definite-lived intangible assets, along with other long-lived assets (utility plant), for
impairment when events or changes in circumstances indicate the assets' fair value might be below their carrying amount.
During the fourth quarter of 2019, in connection with the preparation of the year-end financial statements, we assessed the changes
in circumstances that occurred during the quarter to determine if it was more likely than not that the fair value of our long-lived
assets (including franchise rights) were below their carrying amount. While there was no single determinative event or factor, the
consideration in totality of several factors that developed during the fourth quarter of 2019 led us to conclude that it was more
likely than not that the fair value of the Columbia of Massachusetts reporting unit and the value of its long-lived assets was below
69
Table of Contents
NISOURCE INC.
Notes to Consolidated Financial Statements
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (continued)
its carrying value. These factors included: (i) increased Massachusetts DPU regulatory enforcement activity related to Columbia
of Massachusetts during the fourth quarter, including (a) an order imposing work restrictions on Columbia of Massachusetts,
impacting Columbia of Massachusetts' infrastructure replacement program, (b) two orders opening public investigations into
Columbia of Massachusetts related to the Greater Lawrence Incident and restoration efforts following the incident, and (c) an
order defining the scope of the Massachusetts DPU's investigation into the preparation and response of Columbia of Massachusetts
related to the incident; (ii) increased uncertainty as to the ability of Columbia of Massachusetts to execute its growth strategy,
including utility infrastructure investments, and to obtain timely regulatory outcomes with reasonable rates of return; (iii) further
damage to Columbia of Massachusetts' reputation as a result of concerns related to service lines abandoned during the restoration
work following the Greater Lawrence Incident and the gas release event in Lawrence, Massachusetts on September 27, 2019; and
(iv) the potential sale of the Massachusetts Business. See Note 19, "Other Commitments and Contingencies - C. Legal Proceedings"
for more information regarding Massachusetts DPU regulatory enforcement activity. See Note 26, "Subsequent Event" for more
information on the potential sale of the Massachusetts Business.
As a result, we performed a year-end impairment test of the held and used long-lived assets in which we compared the book value
of the Columbia of Massachusetts asset group to its undiscounted future cash flow and determined the carrying value of the asset
group was not recoverable. We estimated the fair value of the Columbia of Massachusetts asset group using a weighting of income
and market approaches and determined that the fair value was less than the carrying value. This resulting impairment was allocated
to reduce the entire franchise rights book value to its fair value of zero, which resulted in an impairment charge totaling $209.7
million recorded in the Gas Distribution Operations segment.
We also considered if any regulatory assets or ROU assets were probable of disallowance and determined no disallowances were
probable. All of Columbia of Massachusetts' regulatory assets represent incurred costs probable of recovery.
As of December 31, 2019 and 2018, the carrying amount of the franchise rights was $0.0 million and $220.7 million (net of
accumulated amortization of $221.5 million), respectively. We recorded amortization expense of $11.0 million in 2019, 2018 and
2017 related to our franchise rights intangible asset.
Goodwill. Substantially all of our goodwill relates to the excess of cost over the fair value of the net assets acquired in the Columbia
acquisition on November 1, 2000. The following presents our goodwill balance allocated by segment as of December 31, 2019
and 2018:
(in millions)
Gas Distribution Operations
Electric Operations
Corporate and Other
Total
2019
2018
1,485.9
—
—
$
1,690.7
—
—
1,485.9
$
1,690.7
$
$
For our annual goodwill impairment analysis performed as of May 1, 2019, we completed a qualitative "step 0" analysis for all
reporting units other than our Columbia of Massachusetts reporting unit. In the step 0 analysis, we assessed various assumptions,
events and circumstances that would have affected the estimated fair value of the applicable reporting units as compared to their
baseline May 1, 2016 "step 1" fair value measurement. The results of this assessment indicated that it was not more likely than
not that the fair values of these reporting units were less than their respective carrying values, accordingly, no "step 1" analysis
was required.
The results of our Columbia of Massachusetts reporting unit were negatively impacted by the Greater Lawrence Incident (see
Note 19-C, "Legal Proceedings"). As a result, we completed a quantitative "step 1" analysis for the May 1, 2019 goodwill analysis
for this reporting unit. This analysis considered the progress Columbia of Massachusetts had made with its restoration efforts
related to the Greater Lawrence Incident, including the replacement of previously repaired equipment and the settlement agreement
with the three impacted municipalities, as well as the ability for Columbia of Massachusetts to sustain its infrastructure replacement
growth strategy through GSEP and timely rate cases with reasonable rates of return. Consistent with our historical impairment
testing of goodwill, fair value of the Columbia of Massachusetts reporting unit was determined based on a weighting of income
and market approaches. These approaches require significant judgments, including appropriate long-term growth rates and discount
rates for the income approach and appropriate multiples of earnings for peer companies and control premiums for the market
approach. These approaches also incorporate the latest available cash flow projections reflecting the estimated ongoing impacts
of the Greater Lawrence Incident on Columbia of Massachusetts’ operations. The discount rates were derived using peer company
70
Table of Contents
NISOURCE INC.
Notes to Consolidated Financial Statements
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (continued)
data compiled with the assistance of a third party valuation services firm. The discount rates used are subject to change based on
changes in tax rates at both the state and federal level, debt and equity ratios at each reporting unit and general economic conditions.
The long-term growth rate was derived by evaluating historic growth rates, new business and investment opportunities beyond
the near term horizon. The long-term growth rate is subject to change depending on inflationary impacts to the U.S. economy and
the individual business environments in which each reporting unit operates. The step 1 analysis performed indicated that the fair
value of the Columbia of Massachusetts reporting unit exceeds its carrying value. As a result, no impairment charge was recorded
as of the May 1, 2019 test date.
Although our annual impairment test is performed during the second quarter, we continue to monitor changes in circumstances
that may indicate that it is more likely than not that the fair value of our reporting units is less than the reporting unit carrying
value. During the fourth quarter of 2019, in connection with the preparation of the year-end financial statements, we assessed the
matters related to Columbia of Massachusetts. These factors were the same fourth quarter circumstances outlined in the intangible
and other long-lived assets impairment above.
As a result, a new impairment analysis was required for our Columbia of Massachusetts reporting unit. Consistent with the May
1, 2019 test, fair value of this reporting unit was determined based on a weighting of income and market approaches. The income
approach calculated discounted cash flows using updated cash flow projections, discount rates and return on equity assumptions.
The market approach applied a combination of comparable company multiples and comparable transactions and used updated
cash flow projections. While certain assumptions, such as market multiples, remained unchanged in the year-end test, our cash
flow projections, return on equity and rate case assumptions were all unfavorably updated at year-end compared to the May 1,
2019 test. The effects of these unfavorable developments were greater than the favorable change in weighted average cost of
capital between the two tests. The year-end impairment analysis indicated that the fair value of the Columbia of Massachusetts
reporting unit was below its carrying value. As a result, we reduced the Columbia of Massachusetts reporting unit goodwill balance
to zero and recognized a goodwill impairment charge totaling $204.8 million, which is non-deductible for tax purposes.
7.
Asset Retirement Obligations
We have recognized asset retirement obligations associated with various legal obligations including costs to remove and dispose
of certain construction materials located within many of our facilities, certain costs to retire pipeline, removal costs for certain
underground storage tanks, removal of certain pipelines known to contain PCB contamination, closure costs for certain sites
including ash ponds, solid waste management units and a landfill, as well as some other nominal asset retirement obligations. We
also have a significant obligation associated with the decommissioning of our two hydro facilities located in Indiana. These hydro
facilities have an indeterminate life, and as such, no asset retirement obligation has been recorded.
Changes in our liability for asset retirement obligations for the years 2019 and 2018 are presented in the table below:
(in millions)
Beginning Balance
Accretion recorded as a regulatory asset/liability
Additions
Settlements
Change in estimated cash flows
$
2019
2018
$
352.0
15.7
—
(5.4)
54.6 (1)
416.9
268.7
11.1
63.3 (2)
(5.9)
14.8 (2)
352.0
Ending Balance
(1)The change in estimated cash flows for 2019 is primarily attributed to changes in estimated costs and settlement timing for electric generating stations and the
changes in estimated costs for retirement of gas mains.
(2)In 2018, $59.8 million of additions and $17.7 million of the change in estimated cash flows are attributed to costs associated with refining the CCR compliance
plan. See Note 19-D, "Environmental Matters," for additional information on CCRs.
$
$
Certain non-legal costs of removal that have been, and continue to be, included in depreciation rates and collected in the customer
rates of the rate-regulated subsidiaries are classified as "Regulatory liabilities" on the Consolidated Balance Sheets.
8.
Regulatory Matters
Regulatory Assets and Liabilities
We follow the accounting and reporting requirements of ASC Topic 980, which provides that regulated entities account for and
report assets and liabilities consistent with the economic effect of regulatory rate-making procedures if the rates established are
71
Table of Contents
NISOURCE INC.
Notes to Consolidated Financial Statements
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (continued)
designed to recover the costs of providing the regulated service and it is probable that such rates can be charged and collected from
customers. Certain expenses and credits subject to utility regulation or rate determination normally reflected in income or expense
are deferred on the balance sheet and are recognized in the income statement as the related amounts are included in customer rates
and recovered from or refunded to customers.
Regulatory assets were comprised of the following items:
At December 31, (in millions)
Regulatory Assets
2019
2018
Unrecognized pension and other postretirement benefit costs (see Note 11)
$
739.1
$
Deferred pension and other postretirement benefit costs (see Note 11)
Environmental costs (see Note 19-D)
Regulatory effects of accounting for income taxes (see Note 1-N and Note 10)
Under-recovered gas and fuel costs (see Note 1-J)
Depreciation
Post-in-service carrying charges
Safety activity costs
DSM programs
Bailly Generating Station
Other
Total Regulatory Assets
Regulatory liabilities were comprised of the following items:
At December 31, (in millions)
Regulatory Liabilities
Over-recovered gas and fuel costs (see Note 1-J)
Cost of removal (see Note 7)
Regulatory effects of accounting for income taxes (see Note 1-N and Note 10)
Deferred pension and other postretirement benefit costs (see Note 11)
Other
Total Regulatory Liabilities
91.3
73.4
234.0
3.9
210.7
219.8
118.6
50.1
221.8
276.9
798.3
74.1
61.5
233.1
34.7
209.6
206.6
91.7
45.5
244.3
238.1
$
2,239.6
$
2,237.5
2019
2018
$
42.6
$
1,047.5
1,307.0
64.7
50.4
32.0
1,076.0
1,428.3
62.7
61.0
$
2,512.2
$
2,660.0
Regulatory assets, including under-recovered gas and fuel cost, of approximately $1,524.3 million as of December 31, 2019 are
not earning a return on investment. These costs are recovered over a remaining life of up to 41 years. Regulatory assets of
approximately $1,932.4 million include expenses that are recovered as components of the cost of service and are covered by
regulatory orders. Regulatory assets of approximately $307.2 million at December 31, 2019, require specific rate action.
Assets:
Unrecognized pension and other postretirement benefit costs. In 2007, we adopted certain updates of ASC 715 which required,
among other things, the recognition in other comprehensive income or loss of the actuarial gains or losses and the prior service
costs or credits that arise during the period but that are not immediately recognized as components of net periodic benefit costs.
Certain subsidiaries defer these gains or losses as a regulatory asset in accordance with regulatory orders or as a result of regulatory
precedent, to be recovered through base rates.
Deferred pension and other postretirement benefit costs. Primarily relates to the difference between postretirement expense
recorded by certain subsidiaries due to regulatory orders and the postretirement expense recorded in accordance with GAAP. These
costs are expected to be collected through future base rates, revenue riders or tracking mechanisms.
72
Table of Contents
NISOURCE INC.
Notes to Consolidated Financial Statements
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (continued)
Environmental costs. Includes certain recoverable costs of investigating, testing, remediating and other costs related to gas plant
sites, disposal sites or other sites onto which material may have migrated. Certain of our companies defer the costs as a regulatory
asset in accordance with regulatory orders, to be recovered in future base rates, billing riders or tracking mechanisms.
Regulatory effects of accounting for income taxes. Represents the deferral and under collection of deferred taxes in the rate
making process. In prior years, we have lowered customer rates in certain jurisdictions for the benefits of accelerated tax deductions.
Amounts are expensed for financial reporting purposes as we recover deferred taxes in the rate making process.
Under-recovered gas and fuel costs. Represents the difference between the costs of gas and fuel and the recovery of such costs
in revenue and is used to adjust future billings for such deferrals on a basis consistent with applicable state-approved tariff provisions.
Recovery of these costs is achieved through tracking mechanisms.
Depreciation. Represents differences between depreciation expense incurred on a GAAP basis and that prescribed through
regulatory order. Significant components of this balance include:
• Columbia of Ohio depreciation rates. Prior to 2005, the PUCO-approved depreciation rates for rate-making had been
lower than those which would have been utilized if Columbia of Ohio were not subject to regulation resulting in the
creation of a regulatory asset. In 2005, the PUCO authorized Columbia of Ohio to revise its depreciation accrual rates
for the period beginning January 1, 2005. The revised depreciation rates are higher than those which would have been
utilized if Columbia of Ohio were not subject to regulation allowing for amortization of the previously created regulatory
asset. The amount of depreciation that would have been recorded from 2005 through 2019 had Columbia of Ohio not
been subject to rate regulation is a cumulative $923.5 million, $103.8 million less than that reflected in rates. The resulting
regulatory asset balance was $27.9 million and $39.5 million as of December 31, 2019 and 2018, respectively.
• Columbia of Ohio IRP and CEP. Columbia of Ohio also has PUCO approval to defer depreciation and debt-based post-
in-service carrying charges (see "Post-in-service carrying charges" below) associated with its IRP and CEP. As of
December 31, 2019, depreciation of $31.9 million and $77.2 million was deferred for the respective programs.
Depreciation deferral balances for the respective programs as of December 31, 2018 were $29.1 million and $76.0 million.
Recovery of the depreciation is approved annually through the IRP and CEP riders. The equivalent of annual depreciation
expense, based on the average life of the related assets, is included in the calculation of the IRP and CEP riders approved
by the PUCO and billed to customers. Deferred depreciation expense is recognized as the IRP and CEP riders are billed
to customers.
• NIPSCO ECRM. NIPSCO obtained approval from the IURC to recover certain environmental related costs including
operation and maintenance and depreciation expense once the environmental facilities become operational. The ECRM
deferred charges represent expenses that will be recovered from customers through an annual ECRM Cost Tracker (ECT)
which authorizes the collection of deferred balances over a six month period. Depreciation of $15.2 million and $14.4
million was deferred to a regulatory asset as of December 31, 2019 and 2018, respectively. This regulatory asset was
included in electric base rates, which was approved by the IURC on December 4, 2019.
• NIPSCO TDSIC. NIPSCO obtained approval from the IURC to recover costs for certain system modernization projects
outside of a base rate proceeding. Eighty percent of the related costs, including depreciation, property taxes, and debt and
equity based carrying charges (see "Post-in-service carrying charges" below) are recovered through a semi-annual
recovery mechanism. Recovery of these costs will continue through the TDSIC tracker until such assets are included in
rate base through a gas or electric base rate case, respectively. The remaining twenty percent of the costs are deferred
until the next base rate case. As of December 31, 2019 and 2018, depreciation of $22.0 million and $16.5 million,
respectively, was deferred as a regulatory asset.
Post-in-service carrying charges. Represents deferred debt-based carrying charges incurred on certain assets placed into service
but not yet included in customer rates. This balance includes:
• Columbia of Ohio IRP and CEP. See description of IRP and CEP programs above under the heading "Depreciation."
As of December 31, 2019 and 2018, Columbia of Ohio had deferred PISCC of $206.4 million and $197.1 million,
respectively.
• NIPSCO TDSIC. See description of TDSIC program above under the heading "Depreciation." Deferral of equity-based
carrying charges for the TDSIC program is allowed; however, such amounts are not reflected in regulatory asset balances
for financial reporting as equity-based returns do not meet the definition of incurred costs under ASC 980. As of
December 31, 2019 and 2018, NIPSCO had deferred PISCC of $13.4 million and $9.5 million, respectively.
73
Table of Contents
NISOURCE INC.
Notes to Consolidated Financial Statements
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (continued)
Safety activity costs. Represents the difference between costs incurred in eligible safety programs in excess of those being recovered
in rates. The eligible cost deferrals represent necessary business expenses incurred in compliance with PHMSA regulations and
are targeted to enhance the safety of the pipeline systems. Certain subsidiaries defer the excess costs as a regulatory asset in
accordance with regulatory orders and recovery of these costs will be addressed in future base rate proceedings.
DSM programs. Represents costs associated with Gas Distribution Operations and Electric Operations segments' energy efficiency
and conservation programs. Costs are recovered through tracking mechanisms.
Bailly Generating Station. Represents the net book value of Units 7 and 8 of Bailly Generating Station that was retired during
2018. These amounts are currently being amortized at a rate consistent with their inclusion in customer rates.
Liabilities:
Over-recovered gas and fuel costs. Represents the difference between the cost of gas and fuel and the recovery of such costs in
revenues and is the basis to adjust future billings for such refunds on a basis consistent with applicable state-approved tariff
provisions. Refunding of these revenues is achieved through tracking mechanisms.
Cost of removal. Represents anticipated costs of removal that have been, and continue to be, included in depreciation rates and
collected in customer rates of the rate-regulated subsidiaries for future costs to be incurred.
Regulatory effects of accounting for income taxes. Represents amounts owed to customers for deferred taxes collected at a higher
rate than the current statutory rates and liabilities associated with accelerated tax deductions owed to customers that are established
during the rate making process. Balance includes excess deferred taxes recorded upon implementation of the TCJA in December
2017, net of amounts amortized through 2019.
Deferred pension and other postretirement benefit costs. Primarily represents cash contributions in excess of postretirement
benefit expense that is deferred as a regulatory liability by certain subsidiaries in accordance with regulatory orders.
Cost Recovery and Trackers
Comparability of our line item operating results is impacted by regulatory trackers that allow for the recovery in rates of certain
costs such as those described below. Increases in the expenses that are the subject of trackers generally result in a corresponding
increase in operating revenues and, therefore, have essentially no impact on total operating income results.
Certain costs of our operating companies are significant, recurring in nature and generally outside the control of the operating
companies. Some states allow the recovery of such costs through cost tracking mechanisms. Such tracking mechanisms allow for
abbreviated regulatory proceedings in order for the operating companies to implement charges and recover appropriate costs.
Tracking mechanisms allow for more timely recovery of such costs as compared with more traditional cost recovery mechanisms.
Examples of such mechanisms include GCR adjustment mechanisms, tax riders, bad debt recovery mechanisms, electric energy
efficiency programs, MISO non-fuel costs and revenues, resource capacity charges, federally mandated costs and environmental-
related costs.
A portion of the Gas Distribution revenue is related to the recovery of gas costs, the review and recovery of which occurs through
standard regulatory proceedings. All states in our operating area require periodic review of actual gas procurement activity to
determine prudence and to permit the recovery of prudently incurred costs related to the supply of gas for customers. Our distribution
companies have historically been found prudent in the procurement of gas supplies to serve customers.
A portion of the Electric Operations revenue is related to the recovery of fuel costs to generate power and the fuel costs related
to purchased power. These costs are recovered through a FAC, a quarterly regulatory proceeding in Indiana.
Infrastructure Replacement and Federally-Mandated Compliance Programs
All of our operating utility companies have completed rate proceedings involving infrastructure replacement or enhancement, and
have embarked upon initiatives to replace significant portions of their operating systems that are nearing the end of their useful
lives. Each company's approach to cost recovery is unique, given the different laws, regulations and precedent that exist in each
jurisdiction.
Columbia of Ohio, IRP - On December 3, 2008, the PUCO issued an order which established Columbia of Ohio’s IRP. Pursuant
to that order, the IRP provides for recovery of costs resulting from: (1) the maintenance, repair and replacement of customer-owned
service lines that have been determined by Columbia of Ohio to present an existing or probable hazard to persons and property;
74
Table of Contents
NISOURCE INC.
Notes to Consolidated Financial Statements
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (continued)
(2) Columbia of Ohio’s replacement of cast iron, wrought iron, unprotected coated steel and bare steel pipe and associated company
and customer-owned metallic service lines; (3) the replacement of customer-owned natural gas risers identified by the PUCO as
prone to failure; and (4) the installation of AMR devices on all residential and commercial meters served by Columbia of Ohio.
Recoverable costs include a return on investment, depreciation and property taxes, offset by specified cost savings. Columbia of
Ohio’s five-year IRP plan renewal was last approved on January 31, 2018 for the years 2018-2022.
Columbia of Ohio, CEP - On October 3, 2011, Columbia of Ohio filed an application for approval to establish the CEP that would
provide for the deferral of PISCC on those assets placed into service, but not reflected in rates as plant in service, and the deferral
of depreciation expense and property taxes directly attributable to the CEP assets for the period October 1, 2011 through December
31, 2012. Capital expenditures covered under this program included those placed into service that were not part of Columbia of
Ohio's IRP. CEP was approved by the PUCO on August 29, 2012. Under this program, the PUCO’s approval provided for the
deferral of related PISCC, depreciation and property taxes up to the point where the deferred amount, if included in rates, would
exceed $1.50 per month impact on the Small General Service class of customers, subject to the PUCO’s determination of the
prudence and reasonableness of investments covered under this program in a future regulatory proceeding. Subsequently, on
October 3, 2013, the PUCO modified and approved Columbia of Ohio’s application to continue its CEP deferrals in 2013 and
succeeding years, subject to the determination of the prudence, reasonableness and magnitude of the deferrals and capital
expenditures in a future cost recovery proceeding. On December 1, 2017, Columbia of Ohio filed an application in which it
requested authority to implement a rider to begin recovering plant and associated deferrals related to its CEP. On October 25, 2018,
a joint stipulation and recommendation was filed to recover CEP investments and deferrals through December 31, 2017, with
annual adjustments for capital investments made in subsequent years. Additionally, the signatory parties to the stipulation agreed
to a reduction in rates to adjust for the impacts of the Tax Cut Jobs Act and for a base rate case filing to be made by Columbia of
Ohio no later than June 30, 2021. On November 28, 2018 the PUCO issued an order unanimously approving the settlement, without
modification.
NIPSCO Gas and Electric, TDSIC - On April 30, 2013, the Indiana Governor signed Senate Enrolled Act 560, known as the
TDSIC statute, into law. Among other provisions, the TDSIC statute provides for cost recovery outside of a base rate proceeding
for new or replacement electric and gas transmission, distribution, and storage projects that a public utility undertakes for the
purposes of safety, reliability, system modernization or economic development. Provisions of the TDSIC statute require that, among
other things, requests for recovery include a seven-year plan of eligible investments. Once the plan is approved by the IURC,
eighty percent of eligible costs can be recovered using a periodic rate adjustment mechanism, known as the TDSIC mechanism.
Recoverable costs include a return on the investment, including AFUDC, PISCC, depreciation and property taxes. The remaining
twenty percent of recoverable costs are deferred for future recovery in NIPSCO's next general rate case. This rate adjustment
mechanism is typically filed semi-annually and has a cap at an annual increase of two percent of total retail revenues. During the
2019 Legislative session, the Indiana General Assembly amended the TDSIC statute in House Enrolled Act 1470 that was signed
into law by the Governor on April 24, 2019. The revisions that became effective on July 1, 2019 permit flexibility in TDSIC Plans
between five and seven years in length, permits the IURC to authorize multi-unit projects that do not include specific locations or
an exact number of inspections, repairs, or replacements and projects involving advanced technology investments to support the
modernization of transmission, distribution, or storage systems. The amendments also authorize termination of TDSIC Plans prior
to their expiration and provide that the projects associated with the terminated plan will continue to receive TDSIC treatment until
an Order is issued in the utility’s next general rate case, and provide for the ability to seek approval of a new TDSIC Plan. The
amended statute also provides that the two percent revenue cap applies to the aggregate of approved TDSIC Plans and requires
that the utility file a base rate case at some point during the term of each TDSIC plan. On December 31, 2019, NIPSCO Gas filed
a new 6-year TDSIC for the periods 2020 through 2025.
NIPSCO Electric, ECRM - NIPSCO has approval from the IURC to recover certain environmental related costs through an ECT
(environmental cost tracker). Under the ECT, NIPSCO is permitted to recover (1) AFUDC and a return on the capital investment
expended by NIPSCO to implement environmental compliance plan projects and (2) related operation and maintenance and
depreciation expenses once the environmental facilities become operational. All deferred costs associated with ECRM were
included in electric rate base and approved by the IURC on December 4, 2019.
NIPSCO Gas and Electric, FMCA - The FMCA statute provides for cost recovery outside of a base rate proceeding for projected
federally mandated costs. Once the plan is approved by the IURC, eighty percent of eligible costs can be recovered using a periodic
rate adjustment mechanism, known as the FMCA mechanism. Recoverable costs include a return on the investment, including
AFUDC, PISCC, mandated operation and maintenance expenses, depreciation and property taxes. The remaining twenty percent
of recoverable costs are deferred for future recovery in NIPSCO's next general rate case. Actual costs that exceed the projected
75
Table of Contents
NISOURCE INC.
Notes to Consolidated Financial Statements
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (continued)
federally mandated costs of the approved compliance project by more than twenty-five percent shall require specific justification
by NIPSCO and specific approval by the IURC before being authorized in the next general rate case.
Columbia of Massachusetts, GSEP - On July 7, 2014, the Governor of Massachusetts signed into law Chapter 149 of the Acts
of 2014, an Act Relative to Natural Gas Leaks (“the Act”). Adopted into the Massachusetts Utility Provisions, G.L. c. 164, § 145,
the Act authorizes natural gas distribution companies to file a GSEP for capital investments made on or after January 1, 2015,
that are not included in the company’s current rate base as determined in the most recent base rate case, with the Massachusetts
DPU to (1) address the replacement or improvement of existing aging natural gas pipeline infrastructure to improve public safety
or infrastructure reliability, and (2) reduce the lost and unaccounted for natural gas through a reduction in natural gas system leaks.
In addition, the Act provides that the Massachusetts DPU may, after review of the plan, allow the proposed estimated costs of the
plan into rates as of May 1 of the subsequent year. Recoverable costs include a return on investment, depreciation and property
taxes, offset by identified operations and maintenance cost savings. Beginning with the 2019 GSEP, rates are subject to a capped
annual revenue increase of three percent of total annual firm delivery revenues, plus imputed gas revenues for sales and transportation
customers, calculated as the product of (1) the historical average cost of gas per therm, and (2) the average weather normalized
sales, for the period beginning with 2013 and ending with the most recent year that actual data is available at the time of the October
GSEP Plan filing, per the Massachusetts DPU order in Columbia of Massachusetts' 2019 GSEP. Prior to the 2019 GSEP, the
annual revenue increase was capped at one and a half percent. At the end of each 12-month period, in May of the subsequent year,
Columbia of Massachusetts must file a reconciliation of the amount collected and actual costs. Any over-collection or under-
collection balance is passed back to, or recovered from, customers through the surcharge over a 12-month period beginning in
November. On October 31, 2019, the Massachusetts DPU issued an order on Columbia of Massachusetts' GSEP reconciliation
proceeding finding that, due to pending investigations of the Greater Lawrence Incident and other operational matters, the
Massachusetts DPU could not, at this time, make a finding of prudence with respect to the Columbia of Massachusetts' 2018 GSEP
investments and deferred the decision on the prudency of the 2018 GSEP investments in the annual GSEP and GSEP reconciliation
filings until the investigations by the DPU are complete. The DPU added that its inability to make a finding of prudence did not
constitute a finding of imprudence. Once new base rates are established under a base rate proceeding, the GSEP factor is re-set to
remove the capital investment and associated revenue reflected in the base rates. Columbia of Massachusetts' current five year
GSEP plan for the periods 2019-2023 was approved April 30, 2019.
Columbia of Pennsylvania, DSIC - On February 14, 2012, the Governor of Pennsylvania signed into law Act 11 of 2012, which
provided a DSIC mechanism for certain utilities to recover costs related to repair, replacement or improvement of eligible distribution
property that has not previously been reflected in rates or rate base. Through a DSIC, a utility may recover the fixed costs of eligible
infrastructure incurred during the three months ended one month prior to the effective date of the charge, thereby reducing the
historical regulatory lag associated with cost recovery through the traditional rate-making process. On March 14, 2013, the
Pennsylvania PUC approved Columbia of Pennsylvania’s petition to implement a DSIC as of April 1, 2013. Accordingly, Columbia
of Pennsylvania is authorized to recover the cost of eligible plant associated with repair, replacement or improvement that was not
previously reflected in rate base and has been placed in service during the applicable three-month period. After the initial charge
is established, the DSIC is updated quarterly to recover the cost of further plant additions and cannot exceed five percent of
distribution revenues. Recoverable costs include a return on investment, exclusive of accumulated deferred income taxes from the
calculation of rate base, and depreciation. Once new base rates are established under a base rate proceeding, the DSIC is set to
zero. Additionally, the DSIC rate is also reset to zero if, in any quarter, the data reflected in the Columbia of Pennsylvania's most
recent quarterly financial earnings report show that the utility will earn an overall rate of return that would exceed the allowable
rate of return used to calculate its fixed costs under the DSIC mechanism. A utility is exempt from filing a quarterly financial
earnings report when a base rate proceeding is pending before the Pennsylvania PUC.
Columbia of Virginia, SAVE - On March 11, 2010, the Virginia Governor signed legislation into law that allows natural gas
utilities to implement programs to replace qualifying infrastructure on an expedited basis and provides for timely cost recovery.
Known as the SAVE Act, the law allows natural gas utilities to file programs with the VSCC providing a timeline and estimated
costs for replacing eligible infrastructure. Eligible infrastructure replacement projects are those that (1) enhance safety or reliability
by reducing system integrity risks associated with customer outages, corrosion, equipment failures, material failures, or natural
forces; (2) do not increase revenues by directly connecting the infrastructure replacement to new customers; (3) reduce or have
the potential to reduce greenhouse gas emissions; (4) are not included in the natural gas utility’s rate base in its most recent rate
case; and (5) are commenced on or after January 1, 2010. The SAVE Act provides for recovery of costs associated with the eligible
infrastructure through a rate rider. Recoverable costs include a return on investment, depreciation and property taxes. Columbia
of Virginia’s current five year SAVE plan was approved by the VSCC in 2016 and amended in 2017 for the years 2016 through
2020 and amended in 2019 for calendar year 2020.
76
Table of Contents
NISOURCE INC.
Notes to Consolidated Financial Statements
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (continued)
Columbia of Kentucky, SMRP (formerly AMRP) - On October 26, 2009, the Kentucky PSC approved a mechanism for recovering
the costs of Columbia of Kentucky’s AMRP not previously reflected in rate base through an annual fixed monthly rate rider filed
in October. In its 2013 rate case, Columbia of Kentucky was allowed to base the AMRP rider on the expected annual cost of service.
Recoverable costs include a return on investment, depreciation and property taxes, offset by specific cost savings. At the end of
each 12-month period, Columbia of Kentucky must file a reconciliation of the amount collected and actual costs. Any over-
collection or under-collection balance is passed back to, or recovered from, customers through the surcharge over a 12-month
period beginning in June of the subsequent year. Once new base rates are established under a base rate proceeding, the AMRP
rider is set to zero. On July 29, 2019, CKY filed its SMRP to clarify approval of low pressure project spend and expand its AMRP
to include for recovery of system safety investments, including low pressure project spend. On November 7, 2019, the Commission
approved Columbia of Kentucky's request to amend and expand its annual AMRP to become the SMRP.
Columbia of Maryland, STRIDE - On May 2, 2013, the Governor of Maryland signed Senate Bill 8 into law, authorizing gas
companies to accelerate recovery of eligible infrastructure replacement, effective June 1, 2013. The STRIDE statute provides
recovery for gas pipeline upgrades outside of the context of a base rate proceeding through an annual surcharge, IRIS, as approved
by the Maryland PSC. The STRIDE statute directs gas utilities to file a plan to invest in eligible infrastructure replacement projects
and to list the specific projects and elements in any such STRIDE plan with the Maryland PSC. The calendar year projected capital
projects to be placed into plant in service and included in Columbia of Maryland's surcharge recovery request must satisfy a number
of criteria per the statute, including a requirement that they be designed to improve public safety or infrastructure reliability.
Columbia of Maryland’s five-year STRIDE Plan renewal for years 2019 through 2023, as with the preceding five years, is focused
on replacing (1) existing cast iron and bare steel mains, (2) associated services and meters, and (3) identified prone-to-failure
vintage plastic piping. Columbia of Maryland’s IRIS mechanism recovers a return on investment, depreciation and property taxes
of the STRIDE-eligible capital infrastructure statutorily capped at $2 per month for residential customers, and proportionally
capped for commercial and industrial customer classes, and is reconciled to actual costs on an annual basis. Any over-collection
or under-collection balance is passed back to, or recovered from, customers through the surcharge effective in May of the subsequent
year, subject to the cap. STRIDE investments, and recovery thereof, are subject to prudency review by the Maryland PSC in the
context of quarterly STRIDE update filings and in subsequent rate proceedings where STRIDE assets are rolled into rate base for
recovery in base rates.
77
Table of Contents
NISOURCE INC.
Notes to Consolidated Financial Statements
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (continued)
The following table describes the most recent vintage of our regulatory programs to recover infrastructure replacement and other
federally-mandated compliance investments currently in rates and those pending commission approval:
(in millions)
Company
Program
Columbia of Ohio
IRP - 2019(1)
Columbia of Ohio
CEP - 2018
Columbia of Ohio
CEP - 2019
NIPSCO - Gas
NIPSCO - Gas
NIPSCO - Gas
NIPSCO - Gas
NIPSCO - Gas
NIPSCO - Gas
TDSIC 9(1)(2)
TDSIC 10(3)
TDSIC 11(4)
FMCA 1(5)
FMCA 2(5)
FMCA 3(5)
Columbia of Massachusetts
GSEP - 2019(6)
Columbia of Massachusetts
GSEP - 2020(6)(7)
Columbia of Virginia
SAVE - 2019
Columbia of Virginia
SAVE - 2020
Columbia of Kentucky
AMRP - 2019
Columbia of Kentucky
SMRP - 2020
Columbia of Maryland
STRIDE - 2019
Columbia of Maryland
STRIDE - 2020
NIPSCO - Electric
TDSIC - 5(1)
NIPSCO - Electric
TDSIC - 6
NIPSCO - Electric
FMCA - 11(5)
Incremental
Revenue
Incremental
Capital
Investment
Investment
Period
Filed
Status
Rates
Effective
18.2 $
199.6 1/18-12/18
74.5 $
659.9 1/11-12/17
15.0 $
121.7 1/18-12/18
(10.6) $
54.4 1/18-6/18
February 28,
2019
December 1,
2017
February 28,
2019
August 28,
2018
1.6 $
12.4 7/18-4/19
June 25, 2019
Approved
April 24, 2019
May 2019
Approved
November 28, 2018 December 2018
Approved
August 28, 2019
Approved
December 27, 2018
Approved
October 16, 2019
September 2019
January 2019
November 2019
(1.7) $
38.7 5/19-12/19
9.9 $
1.5 11/17-9/18
February 25,
2020
Order Expected
June 2020
November 30,
2018
Approved
March 27, 2019
July 2020
April 2019
(3.5) $
1.8 10/18-3/19 May 29, 2019
Approved
September 25, 2019 October 2019
0.3 $
43.0 4/19-9/19
November 26,
2019
Order Expected
March 2020
9.6 $
36.0 1/19-12/19
2.4 $
75.0 1/20-12/20
2.4 $
36.0 1/19-12/19
3.8 $
50.0 1/20-12/20
3.6 $
30.1 1/19-12/19
4.2 $
40.4 1/20-12/20
October 31,
2018
October 31,
2019
August 17,
2018
August 15,
2019
October 15,
2018
October 15,
2019
Approved
April 30, 2019
Order Expected
April 2020
Approved
October 26, 2018
Approved
December 6, 2019
Approved
December 5, 2018
April 2020
May 2019
May 2020
January 2019
January 2020
January 2019
Approved
December 20, 2019
January 2020
1.2 $
19.7 1/19-12/19
November 1,
2018
Approved
December 12, 2018
January 2019
1.3 $
15.0 1/20-12/20
15.9 $
58.8 6/18-11/18
28.1 $
131.1 12/18-6/19
January 29,
2020
January 29,
2019
August 21,
2019
0.9 $
22.4 9/18-2/19
April 17, 2019
Approved
February 19, 2020
Approved
June 12, 2019
February 2020
June 2019
Approved
December 18, 2019
January 2020
Approved
July 29, 2019
August 2019
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
$
1.6 $
FMCA - 12(5)
NIPSCO - Electric
(1)Incremental revenue is net of amounts due back to customers as a result of the TCJA.
(2)Incremental revenue is net of $5.2 million of adjustments in the TDSIC-9 settlement.
(3)Incremental capital and revenue are net of amounts included in the step 2 rates.
(4)Incremental revenue is net of amounts included in the step 2 rates and reflects a more typical filing period.
(5)Incremental revenue is inclusive of tracker eligible operations and maintenance expense.
(6)Due to an order from the Massachusetts DPU on October 3, 2019 imposing work restrictions on Columbia of Massachusetts, Columbia of Massachusetts did
not meet the approved projected 2019 GSEP spend of $64 million and associated incremental revenue of $10.7 million. In the 2020 GSEP, Columbia of Massachusetts
reduced the projected capital spend for calendar year 2019 to $36 million and the associated incremental revenue in 2019 GSEP to $9.6 million.
(7)Incremental capital investment is anticipated to be lower than $75 million in 2020 due to the Massachusetts DPU imposed work restrictions.
February 2020
4.7 3/19-8/19
October 18,
2019
Approved
January 29, 2020
78
Table of Contents
NISOURCE INC.
Notes to Consolidated Financial Statements
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (continued)
Rate Case Actions
The following table describes current rate case actions as applicable in each of our jurisdictions net of tracker impacts:
(in millions)
Company
NIPSCO - Gas(1)
Columbia of Virginia(2)
NIPSCO - Electric(3)
Requested
Incremental
Revenue
Approved
Incremental
Revenue
Filed
Status
$
$
$
138.1 $
105.6 September 27, 2017
14.2 $
1.3 August 28, 2018
21.4 $
(53.5) October 31, 2018
Approved
September 19, 2018
Approved
June 12, 2019
Approved
December 4, 2019
Rates
Effective
October 2018
February 2019
January 2020
$
2.5 $
Columbia of Maryland
(1)Rates were implemented in three steps, with implementation of step 1 rates effective October 1, 2018. Step 2 rates were effective on March 1, 2019, and step 3
rates were effective on January 1, 2020. The step 3 increase was approved based on actual information and revised from $107.3 million to $105.6 million. The
IURC’s order also dismissed NIPSCO from phase 2 of the IURC’s TCJA investigation.
(2)Rates, as originally filed, were implemented in February 2019 on an interim basis, subject to refund. The final approved rates, which replaced interim rates, were
implemented in July 2019.
(3)An order was received on December 4, 2019, which included the resolution of outstanding TCJA impacts to rates. Incremental revenues decreased due to a
reduction in fuel costs associated with the new industrial service structure. Rates will be implemented in two steps, with implementation of step 1 rates effective
January 2, 2020 and step 2 rates effective March 2, 2020.
(0.1) May 22, 2019
December 2019
Approved
December 18, 2019
Additional Regulatory Matters
NIPSCO Electric. On March 29, 2018, WCE, which is currently owned by BP p.l.c ("BP") and BP Products North America,
which operates the BP Refinery, filed a petition at the IURC asking that the combined operations of WCE and BP be treated as a
single premise, and the WCE generation be dedicated primarily to BP Refinery operations beginning in May 2019 as WCE has
self-certified as a qualifying facility at FERC. BP Refinery planned to continue to purchase electric service from NIPSCO at a
reduced demand level beginning in May 2019; however, a settlement agreement was filed on November 2, 2018 agreeing that BP
and WCE would not move forward with construction of a private transmission line to serve BP until conclusion of NIPSCO’s
pending electric rate case. The IURC approved the settlement agreement as filed on February 20, 2019. On December 4, 2019,
the IURC issued an order in the electric rate case approving the implementation of a new industrial service structure. This resolved
the issues included in BP’s original petition.
The December 4, 2019 electric rate case order approved the revenue requirement settlement filed in the case, with the exception
of a change in the agreed to return on equity; the approved return on equity is 9.75%. The order included approval of the depreciation
rates as requested, as well as authorization to create a regulatory asset upon the retirement of R.M. Schahfer Generating Units 14,
15, 17 and 18 and Michigan City Generating Station Unit 12. The order allows for the recovery of and on the net book value of
the units by the end of 2032.
9.
Risk Management Activities
We are exposed to certain risks relating to ongoing business operations; namely commodity price risk and interest rate risk. We
recognize that the prudent and selective use of derivatives may help to lower our cost of debt capital, manage interest rate exposure
and limit volatility in the price of natural gas.
79
Table of Contents
NISOURCE INC.
Notes to Consolidated Financial Statements
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (continued)
Risk management assets and liabilities on our derivatives are presented on the Consolidated Balance Sheets as shown below:
December 31, (in millions)
Risk Management Assets - Current(1)
Interest rate risk programs
Commodity price risk programs
Total
Risk Management Assets - Noncurrent(2)
Interest rate risk programs
Commodity price risk programs
Total
Risk Management Liabilities - Current(3)
Interest rate risk programs
Commodity price risk programs
Total
Risk Management Liabilities - Noncurrent
Interest rate risk programs
Commodity price risk programs
Total
(1)Presented in "Prepayments and other" on the Consolidated Balance Sheets.
(2)Presented in "Deferred charges and other" on the Consolidated Balance Sheets.
(3)Presented in "Other accruals" on the Consolidated Balance Sheets.
2019
2018
$
$
$
$
$
$
$
$
— $
0.6
0.6
$
— $
3.8
3.8
$
— $
12.6
12.6
76.2
57.8
134.0
$
$
$
—
1.1
1.1
18.5
4.4
22.9
—
5.0
5.0
9.5
37.2
46.7
Commodity Price Risk Management
We, along with our utility customers, are exposed to variability in cash flows associated with natural gas purchases and volatility
in natural gas prices. We purchase natural gas for sale and delivery to our retail, commercial and industrial customers, and for most
customers the variability in the market price of gas is passed through in their rates. Some of our utility subsidiaries offer programs
whereby variability in the market price of gas is assumed by the respective utility. The objective of our commodity price risk
programs is to mitigate the gas cost variability, for us or on behalf of our customers, associated with natural gas purchases or sales
by economically hedging the various gas cost components using a combination of futures, options, forwards or other derivative
contracts.
NIPSCO received IURC approval to lock in a fixed price for its natural gas customers using long-term forward purchase instruments.
The term of these instruments range from five to ten years and is limited to twenty percent of NIPSCO’s average annual GCA
purchase volume. Gains and losses on these derivative contracts are deferred as regulatory liabilities or assets and are remitted to
or collected from customers through NIPSCO’s quarterly GCA mechanism. These instruments are not designated as accounting
hedges.
Interest Rate Risk Management
As of December 31, 2019, we have forward-starting interest rate swaps with an aggregate notional value totaling $500.0 million
to hedge the variability in cash flows attributable to changes in the benchmark interest rate during the periods from the effective
dates of the swaps to the anticipated dates of forecasted debt issuances, which are expected to take place by the end of 2024. These
interest rate swaps are designated as cash flow hedges. The effective portions of the gains and losses related to these swaps are
recorded to AOCI and are recognized in "Interest expense, net" concurrently with the recognition of interest expense on the
associated debt, once issued. If it becomes probable that a hedged forecasted transaction will no longer occur, the accumulated
gains or losses on the derivative will be recognized currently in "Other, net" in the Statements of Consolidated Income (Loss).
The passage of the TCJA and Greater Lawrence Incident led to significant changes to our long-term financing plan. As a result,
during 2018, we settled forward-starting interest rate swaps with a notional value of $750.0 million. These derivative contracts
were accounted for as cash flow hedges. As part of the transactions, the associated net unrealized gain of $46.2 million was
recognized immediately in "Other, net" on the Statements of Consolidated Income (Loss) due to the probability associated with
the forecasted borrowing transactions no longer occurring.
80
Table of Contents
NISOURCE INC.
Notes to Consolidated Financial Statements
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (continued)
There were no amounts excluded from effectiveness testing for derivatives in cash flow hedging relationships at December 31,
2019, 2018 and 2017.
Our derivative instruments measured at fair value as of December 31, 2019 and 2018 do not contain any credit-risk-related
contingent features.
10.
Income Taxes
Income Tax Expense
The components of income tax expense (benefit) were as follows:
Year Ended December 31, (in millions)
Income Taxes
Current
Federal
State
Total Current
Deferred
Federal
State
Total Deferred
Deferred Investment Credits
Income Taxes
Statutory Rate Reconciliation
2019
2018
2017
$
$
— $
5.2
5.2
110.7
9.0
119.7
(1.4)
123.5
$
— $
8.2
8.2
(209.4)
22.2
(187.2)
(1.0)
(180.0) $
—
7.8
7.8
302.7
5.0
307.7
(1.0)
314.5
The following table represents a reconciliation of income tax expense at the statutory federal income tax rate to the actual income
tax expense from continuing operations:
Year Ended December 31, (in millions)
Book income (loss) before income taxes
Tax expense (benefit) at statutory federal income tax rate
Increases (reductions) in taxes resulting from:
State income taxes, net of federal income tax benefit
Amortization of regulatory liabilities
Goodwill impairment
Fines and penalties
Charitable contribution carryover
State regulatory proceedings
Remeasurement due to TCJA
Employee stock ownership plan dividends and other
compensation
Other adjustments
Income Taxes
2019
2018
2017
$
506.6
106.5
$ (230.6)
(48.4)
$
443.0
155.0
21.0%
21.0%
35.0%
10.1
(29.4)
43.0
11.5
(2.5)
(9.5)
—
(2.0)
(4.2)
2.0
(5.8)
8.5
2.3
(0.5)
(1.9)
—
(0.4)
(0.8)
24.7
(29.3)
—
0.2
—
(127.8)
—
(10.7)
12.7
—
(0.1)
—
55.4
—
6.9
(2.4)
—
2.8
(1.2)
—
1.5
(0.5)
—
0.6
(0.3)
—
161.1
36.4
(2.2)
2.8
1.0
(1.2)
(6.5)
(1.2)
(1.5)
(0.2)
$
123.5
24.4% $ (180.0)
78.1% $
314.5
71.0%
The effective income tax rates were 24.4%, 78.1% and 71.0% in 2019, 2018 and 2017, respectively. The 53.7% decrease in effective
tax rate in 2019 versus 2018 was primarily the result of not having significant income tax decreases resulting from state regulatory
proceedings as in 2018. Additionally, there was an increase in the effective tax rate related to the non-cash impairment of goodwill
in 2019 related to Columbia of Massachusetts (see Note 6, "Goodwill and Other Intangible Assets" for additional information)
81
Table of Contents
NISOURCE INC.
Notes to Consolidated Financial Statements
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (continued)
and non-deductible fines and penalties related to the Greater Lawrence Incident (see Note 19, "Legal Proceedings" for additional
information). The rate is also impacted by the relative impact of permanent differences on higher pre-tax income.
The 7.1% increase in the overall effective tax rate in 2018 versus 2017 was primarily the result of state regulatory proceedings
which resulted in a $127.8 million decrease in federal income taxes offset by a related increase in state income taxes of $7.1 million.
Additionally, the increase was driven by a $26.9 million decrease in income taxes related to amortization of the regulatory liability
primarily associated with excess deferred taxes.
Net Deferred Income Tax Liability Components
Deferred income taxes result from temporary differences between the financial statement carrying amounts and the tax basis of
existing assets and liabilities. The principal components of our net deferred tax liability were as follows:
At December 31, (in millions)
Deferred tax liabilities
2019
2018
Accelerated depreciation and other property differences
$
2,516.9
$
Other regulatory assets
Total Deferred Tax Liabilities
Deferred tax assets
Other regulatory liabilities and deferred investment tax credits (including TCJA)
Pension and other postretirement/postemployment benefits
Net operating loss carryforward and AMT credit carryforward
Environmental liabilities
Other accrued liabilities
Other, net
Total Deferred Tax Assets
Net Deferred Tax Liabilities
381.5
2,898.4
336.1
152.1
765.9
25.4
35.3
98.3
1,413.1
$
1,485.3
$
2,458.0
375.4
2,833.4
365.5
157.5
849.8
24.4
37.5
68.2
1,502.9
1,330.5
At December 31, 2019, we had $657.1 million of federal net operating loss carryforwards. The federal net operating loss
carryforwards are available to offset taxable income and will begin to expire in 2028. We also have $1.6 million of federal alternative
minimum tax credit carryforwards which do not expire. In addition, we have $1.4 million in charitable contribution carryforwards
to offset future taxable income, which begin to expire in 2023. We also have $107.2 million (net) of state net operating loss
carryforwards. Depending on the jurisdiction in which the state net operating loss was generated, the carryforwards will begin to
expire in 2028. We believe it is more likely than not that we will realize the benefit from the state net operating loss carryforwards.
Unrecognized Tax Benefits
A reconciliation of the beginning and ending amounts of unrecognized tax benefits is as follows:
Reconciliation of Unrecognized Tax Benefits (in millions)
Unrecognized Tax Benefits - Opening Balance
Gross decreases - tax positions in prior period
Gross increases - current period tax positions
Unrecognized Tax Benefits - Ending Balance
Offset for net operating loss carryforwards
Balance - Less Net Operating Loss Carryforwards
2019
2018
2017
$
$
$
1.2
(0.6)
22.6
23.2
(22.6)
0.6
$
$
$
1.4
(0.4)
0.2
1.2
—
1.2
$
$
$
2.6
(1.4)
0.2
1.4
—
1.4
In 2019, we resolved prior unrecognized tax benefits of $0.6 million and established new unrecognized tax benefits related to state
matters of $22.6 million. We present accrued interest on unrecognized tax benefits, accrued interest on other income tax liabilities
and tax penalties in "Income Taxes" on our Statements of Consolidated Income (Loss). Interest expense recorded on unrecognized
tax benefits and other income tax liabilities was immaterial for all periods presented. There were no accruals for penalties recorded
in the Statements of Consolidated Income (Loss) for the years ended December 31, 2019, 2018 and 2017, and there were no
balances for accrued penalties recorded on the Consolidated Balance Sheets as of December 31, 2019 and 2018.
82
Table of Contents
NISOURCE INC.
Notes to Consolidated Financial Statements
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (continued)
We are subject to income taxation in the United States and various state jurisdictions, primarily Indiana, Pennsylvania, Kentucky,
Massachusetts, Maryland and Virginia.
We participate in the IRS CAP which provides the opportunity to resolve tax matters with the IRS before filing each year's
consolidated federal income tax return. As of December 31, 2019, tax years through 2018 have been audited and are effectively
closed to further assessment. The audit of tax year 2019 under the CAP program is expected to be completed in 2020.
The statute of limitations in each of the state jurisdictions in which we operate remains open until the years are settled for federal
income tax purposes, at which time amended state income tax returns reflecting all federal income tax adjustments are filed. As
of December 31, 2019, there were no state income tax audits in progress that would have a material impact on the consolidated
financial statements.
In December 22, 2017, the TCJA was signed into law. As a result of the implementation of the TCJA, we remeasured deferred
taxes and recognized $161.1 million of income tax expense in our Consolidated Statements of Income (Loss) for the year ended
December 31, 2017. The result of this remeasurement was a reduction in the net deferred tax liability of approximately $1.3 billion,
including approximately $0.4 billion of regulatory "gross up" to account for over collection of past taxes from customers. Offsetting
the reduction in net deferred tax liabilities was an increase in regulatory liabilities of approximately $1.5 billion as of December
31, 2017. In 2018, we received regulatory orders on the treatment of excess deferred taxes from the jurisdictions in which we
operate. As a result of these orders, we reduced our regulatory liability related to excess deferred income taxes by $120.7 million
(net of tax). This adjustment is reflected in "Income Taxes" on our Consolidated Statements of Income (Loss) for the year ended
December 31, 2018.
As of December 31, 2019, we received approval from regulators to return excess deferred taxes in all of our jurisdictions in
accordance with regulatory proceedings.
On December 22, 2017, the SEC issued Staff Accounting Bulletin 118 ("SAB 118"), which provides guidance on accounting for
tax effects of the TCJA. SAB 118 provides a measurement period that should not extend beyond one year from the TCJA enactment
date for companies to complete the accounting under ASC 740. There were no adjustments recorded in the SAB 118 remeasurement
period in 2018.
11.
Pension and Other Postretirement Benefits
We provide defined contribution plans and noncontributory defined benefit retirement plans that cover certain of our employees.
Benefits under the defined benefit retirement plans reflect the employees’ compensation, years of service and age at retirement.
Additionally, we provide health care and life insurance benefits for certain retired employees. The majority of employees may
become eligible for these benefits if they reach retirement age while working for us. The expected cost of such benefits is accrued
during the employees’ years of service. Current rates of rate-regulated companies include postretirement benefit costs, including
amortization of the regulatory assets that arose prior to inclusion of these costs in rates. For most plans, cash contributions are
remitted to grantor trusts.
Our Pension and Other Postretirement Benefit Plans’ Asset Management. We employ a liability-driven investing strategy for
the pension plan, as noted below. A mix of equities and fixed income investments are used to maximize the long-term return of
plan assets and hedge the liabilities at a prudent level of risk. We utilize a total return investment approach for the other postretirement
benefit plans. Risk tolerance is established through careful consideration of plan liabilities, plan funded status, and asset class
volatility. The investment portfolio contains a diversified blend of equity and fixed income investments. Furthermore, equity
investments are diversified across U.S. and non-U.S. stocks, as well as growth, value, small and large capitalizations. Other assets
such as private equity funds are used judiciously 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 may not be used to leverage the
portfolio beyond the market value of the underlying assets. Investment risk is measured and monitored on an ongoing basis through
quarterly investment portfolio reviews, annual liability measurements, and periodic asset/liability studies.
We utilize a building block approach with proper consideration of diversification and rebalancing in determining the long-term
rate of return for plan assets. Historical markets are studied and long-term historical relationships between equities and fixed
income are analyzed to ensure that they are consistent with the widely accepted capital market principle that assets with higher
volatility generate greater return over the long run. Current market factors, such as inflation and interest rates, are evaluated before
long-term capital market assumptions are determined. Peer data and historical returns are reviewed to check for reasonability and
appropriateness.
83
Table of Contents
NISOURCE INC.
Notes to Consolidated Financial Statements
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (continued)
The most important component of an investment strategy is the portfolio asset mix, or the allocation between the various classes
of securities available to the pension and other postretirement benefit plans for investment purposes. The asset mix and acceptable
minimum and maximum ranges established for our plan assets represents a long-term view and are listed in the table below.
In 2012, a dynamic asset allocation policy for the pension fund was approved. This policy calls for a gradual reduction in the
allocation of return-seeking assets (equities, real estate and private equity) and a corresponding increase in the allocation of liability-
hedging assets (fixed income) as the funded status of the plans increase above 90% (as measured by the market value of qualified
pension plan assets divided by the projected benefit obligations of the qualified pension plans). A new asset-liability study was
completed in 2018 resulting in a more conservative glide path and an increase in the allocation to liability-hedging assets held in
the portfolio.
As of December 31, 2019, the asset mix and acceptable minimum and maximum ranges established by the policy for the pension
and other postretirement benefit plans are as follows:
Asset Mix Policy of Funds:
Asset Category
Domestic Equities
International Equities
Fixed Income
Real Estate
Short-Term Investments/Other
Defined Benefit Pension Plan
Maximum
Minimum
32%
12%
16%
6%
71%
59%
7%
0%
15%
0%
Postretirement Benefit Plan
Maximum
Minimum
55%
0%
25%
0%
100%
20%
0%
0%
10%
0%
As of December 31, 2018, the asset mix and acceptable minimum and maximum ranges established by the policy for the pension
and other postretirement benefit plans were as follows:
Asset Mix Policy of Funds:
Asset Category
Domestic Equities
International Equities
Fixed Income
Real Estate
Short-Term Investments/Other
Defined Benefit Pension Plan
Maximum
Minimum
32%
12%
16%
6%
71%
59%
7%
0%
15%
0%
Postretirement Benefit Plan
Maximum
Minimum
55%
0%
25%
0%
100%
20%
0%
0%
10%
0%
84
Table of Contents
NISOURCE INC.
Notes to Consolidated Financial Statements
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (continued)
Pension Plan and Postretirement Plan Asset Mix at December 31, 2019 and December 31, 2018:
Asset Class (in millions)
Domestic Equities
International Equities
Fixed Income
Real Estate
Cash/Other
Total
Asset Class (in millions)
Domestic Equities
International Equities
Fixed Income
Real Estate
Cash/Other
Total
Defined Benefit
Pension Assets
Asset Value
December 31,
2019
% of Total
Assets
Postretirement
Benefit Plan
Assets
Asset Value
December 31,
2019
% of Total
Assets
$
446.4
205.0
1,337.2
53.9
38.4
21.5% $
9.9%
64.2%
2.6%
1.8%
$
2,080.9
100.0% $
93.8
40.7
119.5
—
7.4
261.4
35.9%
15.6%
45.7%
—
2.8%
100.0%
Defined Benefit
Pension Assets
Asset Value
December 31,
2018
% of Total
Assets
Postretirement
Benefit Plan
Assets
Asset Value
December 31,
2018
% of Total
Assets
$
355.5
165.5
1,241.9
52.7
52.1
19.0% $
8.9%
66.5%
2.8%
2.8%
$
1,867.7
100.0% $
78.8
17.5
115.1
—
4.9
216.3
36.4%
8.1%
53.2%
—
2.3%
100.0%
The categorization of investments into the asset classes in the table above are based on definitions established by our Benefits
Committee.
Fair Value Measurements. The following table sets forth, by level within the fair value hierarchy, the Master Trust and other
postretirement benefits investment assets at fair value as of December 31, 2019 and 2018. Assets and liabilities are classified in
their entirety based on the lowest level of input that is significant to the fair value measurement. Total Master Trust and other
postretirement benefits investment assets at fair value classified within Level 3 were $0 million and $86.1 million as of December 31,
2019 and December 31, 2018, respectively. Such amounts were approximately 0% and 4% of the Master Trust and other
postretirement benefits’ total investments as reported on the statement of net assets available for benefits at fair value as of
December 31, 2019 and 2018, respectively.
Valuation Techniques Used to Determine Fair Value:
Level 1 Measurements
Most common and preferred stocks are traded in active markets on national and international securities exchanges and are
valued at closing prices on the last business day of each period presented. Cash is stated at cost which approximates fair
value, with the exception of cash held in foreign currencies which fluctuates with changes in the exchange rates. Short-term
bills and notes are priced based on quoted market values.
Level 2 Measurements
Most U.S. Government Agency obligations, mortgage/asset-backed securities, and corporate fixed income securities are
generally valued by benchmarking model-derived prices to quoted market prices and trade data for identical or comparable
securities. To the extent that quoted prices are not available, fair value is determined based on a valuation model that includes
inputs such as interest rate yield curves and credit spreads. Securities traded in markets that are not considered active are
valued based on quoted market prices, broker or dealer quotations, or alternative pricing sources with reasonable levels of
price transparency. Other fixed income includes futures and options which are priced on bid valuation or settlement pricing.
85
Table of Contents
NISOURCE INC.
Notes to Consolidated Financial Statements
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (continued)
Level 3 Measurements
Investments with unobservable inputs that are supported by little or no market activity and that are significant to the fair
value of the assets and liabilities are classified as level 3 investments.
Not Classified
Commingled funds, private equity limited partnerships and real estate partnerships hold underlying investments that have
prices derived from quoted prices in active markets and are not classified within the fair value hierarchy. Instead, these assets
are measured at estimated fair value using the net asset value per share of the investments. Commingled funds' underlying
assets are principally marketable equity and fixed income securities. Units held in commingled funds are valued at the unit
value as reported by the investment managers. Private equity and real estate funds invest in natural resources, commercial
real estate and distressed real estate. The fair value of these investments is determined by reference to the funds’ underlying
assets.
For the year ended December 31, 2019, there were no significant changes to valuation techniques to determine the fair value of
our pension and other postretirement benefits' assets.
86
Table of Contents
NISOURCE INC.
Notes to Consolidated Financial Statements
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (continued)
Fair Value Measurements at December 31, 2019:
(in millions)
Pension plan assets:
Cash
Fixed income securities
Government
Corporate
Mutual Funds
U.S. multi-strategy
International equities
Private equity limited partnerships(3)
U.S. multi-strategy(1)
International multi-strategy(2)
Distressed opportunities
Real estate
Commingled funds(3)
Short-term money markets
U.S. equities
International equities
Fixed income
Pension plan assets subtotal
Other postretirement benefit plan assets:
Mutual funds
U.S. multi-strategy
International equities
Fixed income
Commingled funds(3)
Short-term money markets
U.S. equities
International equities
Other postretirement benefit plan assets
subtotal
Due to brokers, net(4)
Accrued income/dividends
December 31,
2019
Quoted Prices in
Active Markets for
Identical Assets
(Level 1)
Significant Other
Observable Inputs
(Level 2)
Significant
Unobservable Inputs
(Level 3)
$
6.7
$
6.7
$
— $
319.6
651.8
140.5
56.9
14.0
8.5
0.5
53.9
14.8
305.9
148.1
351.8
2,073.0
81.7
20.6
119.2
7.7
12.1
20.1
261.4
(2.8)
10.7
—
—
140.5
56.9
—
—
—
—
—
—
—
—
319.6
651.8
—
—
—
—
—
—
—
—
—
—
204.1
971.4
81.7
20.6
119.2
—
—
—
221.5
—
10.7
—
—
—
—
—
—
—
(2.8)
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
Total pension and other postretirement
$
benefit plan assets
(1) This class includes limited partnerships/fund of funds that invest in a diverse portfolio of private equity strategies, including buy-outs, venture capital, growth
capital, special situations and secondary markets, primarily inside the United States.
(2) This class includes limited partnerships/fund of funds that invest in diverse portfolio of private equity strategies, including buy-outs, venture capital, growth
capital, special situations and secondary markets, primarily outside the United States.
(3) This class of investments is measured at fair value using the net asset value per share and has not been classified in the fair value hierarchy.
(4) This class represents pending trades with brokers.
2,342.3
436.3
968.6
—
$
$
$
87
Table of Contents
NISOURCE INC.
Notes to Consolidated Financial Statements
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (continued)
The table below sets forth a summary of changes in the fair value of the Plan’s Level 3 assets for the year ended December 31,
2019:
Private equity limited partnerships
U.S. multi-strategy
International multi-strategy
Distressed opportunities
Real estate
Total
Balance at
January 1,
2019
Transfers out
(Level 3)(1)
Balance at
December 31,
2019
18.5
12.5
2.4
52.7
(18.5)
(12.5)
(2.4)
(52.7)
$
86.1
$
(86.1) $
—
—
—
—
—
(1) Level 3 assets from the prior year were reclassified in the current year presentation and included within the fair value hierarchy table as of December 31, 2019
as “Not Classified" investments for which fair value is measured using net asset value per share, consistent with the definitions described above.
The table below sets forth a summary of unfunded commitments, redemption frequency and redemption notice periods for certain
investments that are measured at fair value using the net asset value per share for the year ended December 31, 2019:
(in millions)
Commingled Funds
Short-term money markets
U.S. equities
International equities
Fixed income
Total
Fair Value
Redemption
Frequency
Redemption
Notice Period
$
$
22.5
318.0
168.2
351.8
860.5
Daily
Monthly
Monthly
Daily
1 day
1 day
10-30 days
3 days
88
Table of Contents
NISOURCE INC.
Notes to Consolidated Financial Statements
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (continued)
Fair Value Measurements at December 31, 2018:
(in millions)
Pension plan assets:
Cash
Equity securities
U.S. equities
Fixed income securities
Government
Corporate
Mutual Funds
U.S. multi-strategy
International equities
Fixed income
Private equity limited partnerships
U.S. multi-strategy(1)
International multi-strategy(2)
Distressed opportunities
Real Estate
Commingled funds(3)
Short-term money markets
U.S. equities
International equities
Fixed income
Pension plan assets subtotal
Other postretirement benefit plan assets:
Mutual funds
U.S. equities
International equities
Fixed income
Commingled funds(3)
Short-term money markets
U.S. equities
Other postretirement benefit plan assets
subtotal
Due to brokers, net(4)
Accrued investment income/dividends
December 31,
2018
Quoted Prices in
Active Markets for
Identical Assets
(Level 1)
Significant Other
Observable Inputs
(Level 2)
Significant
Unobservable Inputs
(Level 3)
$
9.2
$
8.8
$
0.4
$
0.2
250.2
442.8
110.3
43.2
166.8
18.5
12.5
2.4
52.7
18.3
245.2
122.3
365.7
1,860.3
68.4
17.5
114.8
5.2
10.4
216.3
(1.1)
8.6
0.2
—
—
110.3
43.2
166.8
—
—
—
—
—
—
—
—
—
250.2
442.8
—
—
—
—
—
—
—
—
—
—
—
329.3
693.4
68.4
17.5
114.8
—
—
200.7
—
8.6
—
—
—
—
—
—
(1.1)
—
—
—
—
—
—
—
—
18.5
12.5
2.4
52.7
—
—
—
—
86.1
—
—
—
—
—
—
—
—
Total pension and other postretirement
benefit plan assets
$
$
(1) This class includes limited partnerships/fund of funds that invest in a diverse portfolio of private equity strategies, including buy-outs, venture capital, growth
capital, special situations and secondary markets, primarily inside the United States.
(2) This class includes limited partnerships/fund of funds that invest in a diverse portfolio of private equity strategies, including buy-outs, venture capital, growth
capital, special situations and secondary markets, primarily outside the United States.
(3) This class of investments is measured at fair value using the net asset value per share and has not been classified in the fair value hierarchy.
(4) This class represents pending trades with brokers.
2,084.1
538.6
692.3
86.1
$
$
89
Table of Contents
NISOURCE INC.
Notes to Consolidated Financial Statements
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (continued)
The table below sets forth a summary of changes in the fair value of the Plan’s Level 3 assets for the year ended December 31,
2018:
Private equity limited partnerships
U.S. multi-strategy
International multi-strategy
Distress opportunities
Real estate
Total
Balance at
January 1,
2018
Total gains or
losses (unrealized
/ realized)
Purchases
(Sales)
Balance at
December 31,
2018
26.7
19.1
3.2
49.9
98.9
$
$
2.4
(0.6)
(0.8)
1.7
2.7
$
0.7
—
—
1.8
2.5
$
(11.3)
(6.0)
—
(0.7)
(18.0) $
18.5
12.5
2.4
52.7
86.1
The table below sets forth a summary of unfunded commitments, redemption frequency and redemption notice periods for certain
investments that are measured at fair value using the net asset value per share for the year ended December 31, 2018:
(in millions)
Commingled Funds
Short-term money markets
U.S. equities
International equities
Fixed income
Total
Fair Value
Redemption
Frequency
Redemption
Notice Period
$
$
23.5
255.6
122.3
365.7
767.1
Daily
Monthly
Monthly
Monthly
1 day
3 days
10-30 days
3 days
90
Table of Contents
NISOURCE INC.
Notes to Consolidated Financial Statements
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (continued)
Our Pension and Other Postretirement Benefit Plans’ Funded Status and Related Disclosure. The following table provides a
reconciliation of the plans’ funded status and amounts reflected in our Consolidated Balance Sheets at December 31 based on a
December 31 measurement date:
Pension Benefits
Other Postretirement Benefits
2019
2018
2019
2018
(in millions)
Change in projected benefit obligation(1)
Benefit obligation at beginning of year
Service cost
Interest cost
Plan participants’ contributions
Plan amendments
Actuarial (gain) loss
Settlement loss
Benefits paid
Estimated benefits paid by incurred subsidy
Projected benefit obligation at end of year
Change in plan assets
Fair value of plan assets at beginning of year
Actual (loss) return on plan assets
Employer contributions
Plan participants’ contributions
Benefits paid
Fair value of plan assets at end of year
Funded Status at end of year
Amounts recognized in the statement of
financial position consist of:
Noncurrent assets
Current liabilities
Noncurrent liabilities
Net amount recognized at end of year(2)
Amounts recognized in accumulated other
comprehensive income or regulatory asset/liability(3)
Unrecognized prior service credit
Unrecognized actuarial loss
$
$
$
$
$
$
$
$
$
$
1,981.3
29.2
72.3
—
—
204.3
—
(156.6)
—
2,130.5
1,867.7
366.8
2.9
—
(156.5)
2,080.9
$
(49.6) $
8.2
(3.0)
(54.8)
(49.6) $
$
3.0
652.8
655.8
2,192.6
31.3
67.1
—
0.2
(103.9)
0.8
(206.8)
—
1,981.3
$
$
$
2,160.0
(88.4)
2.9
—
(206.8)
$
1,867.7
(113.6) $
—
(3.0)
(110.6)
(113.6) $
492.5
5.1
19.2
4.8
5.1
88.8
—
(39.5)
0.5
576.5
$
$
$
216.3
56.9
23.0
4.7
(39.5)
261.4
$
(315.1) $
—
(0.8)
(314.3)
(315.1) $
556.3
5.0
17.6
5.7
0.1
(51.7)
—
(41.1)
0.6
492.5
262.5
(31.8)
21.0
5.7
(41.1)
216.3
(276.2)
—
(0.8)
(275.4)
(276.2)
$
3.2
761.2
764.4
(10.7) $
118.4
107.7
(19.0)
75.3
56.3
$
Net amount recognized at end of year
(1) The change in benefit obligation for Pension Benefits represents the change in Projected Benefit Obligation while the change in benefit obligation for Other
Postretirement Benefits represents the change in accumulated postretirement benefit obligation.
(2) We recognize our Consolidated Balance Sheets underfunded and overfunded status of our various defined benefit postretirement plans, measured as the difference
between the fair value of the plan assets and the benefit obligation.
(3) We determined that for certain rate-regulated subsidiaries the future recovery of pension and other postretirement benefits costs is probable. These rate-regulated
subsidiaries recorded regulatory assets and liabilities of $739.1 million and $0.1 million, respectively, as of December 31, 2019, and $798.3 million and $0.1
million, respectively, as of December 31, 2018 that would otherwise have been recorded to accumulated other comprehensive loss.
$
$
$
Our accumulated benefit obligation for our pension plans was $2,111.5 million and $1,965.6 million as of December 31, 2019 and
2018, respectively. The accumulated benefit obligation as of a date is the actuarial present value of benefits attributed by the pension
benefit formula to employee service rendered prior to that date and based on current and past compensation levels. The accumulated
benefit obligation differs from the projected benefit obligation disclosed in the table above in that it includes no assumptions about
future compensation levels.
We are required to reflect the funded status of the pension and postretirement benefit plans on the Consolidated Balance Sheet.
The funded status of the plans is measured as the difference between the plan assets' fair value and the projected benefit obligation.
We present the noncurrent aggregate of all underfunded plans within "Accrued liability for postretirement and postemployment
benefits." The portion of the amount by which the actuarial present value of benefits included in the projected benefit obligation
91
Table of Contents
NISOURCE INC.
Notes to Consolidated Financial Statements
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (continued)
exceeds the fair value of plan assets, payable in the next 12 months, is reflected in "Accrued compensation and other benefits."
We present the aggregate of all overfunded plans within "Deferred charges and other."
Information for pension plans with a projected benefit obligation in excess of plan assets:
Accumulated Benefit Obligation
Funded Status
Projected Benefit Obligation
Fair Value of Plan Assets
Funded Status of Underfunded Pension Plans at End of Year
Information for pension plans with plan assets in excess of the projected benefit obligation:
Accumulated Benefit Obligation
Funded Status
Projected Benefit Obligation
Fair Value of Plan Assets
Funded Status of Overfunded Pension Plans at End of Year
December 31,
2019
2018
$
1,473.9
$
1,965.6
1,492.9
1,435.1
(57.8) $
1,981.3
1,867.7
(113.6)
December 31,
2019
2018
637.6
$
637.6
645.8
8.2
$
—
—
—
—
$
$
$
Our pension plans were underfunded,
being underfunded by $113.6 million at December 31, 2018. The improvement in the funded status was due primarily to favorable
asset returns offset by a decrease in discount rates. We contributed $2.9 million to our pension plans in both 2019 and 2018.
in aggregate, by $49.6 million at December 31, 2019 compared
to
Our other postretirement benefit plans were underfunded by $315.1 million at December 31, 2019 compared to being underfunded
by $276.2 million at December 31, 2018. The decline in funded status was primarily due to a decrease in discount rates offset by
favorable asset returns. We contributed $23.0 million and $21.0 million to our other postretirement benefit plans in 2019 and 2018,
respectively.
No amounts of our pension or other postretirement benefit plans’ assets are expected to be returned to us or any of our subsidiaries
in 2019.
In 2019 and 2018, some of our qualified pension plans paid lump sum payouts in excess of the respective plan's service cost plus
interest cost, thereby meeting the requirement for settlement accounting. We recorded settlement charges of $9.5 million and $18.5
million in 2019 and 2018, respectively. Net periodic pension benefit cost for 2019 was decreased by $0.7 million as a result of the
interim remeasurement.
92
Table of Contents
NISOURCE INC.
Notes to Consolidated Financial Statements
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (continued)
The following table provides the key assumptions that were used to calculate the pension and other postretirement benefits
obligations for our various plans as of December 31:
Weighted-average assumptions to Determine Benefit
Obligation
Discount Rate
Rate of Compensation Increases
Health Care Trend Rates
Trend for Next Year
Ultimate Trend
Year Ultimate Trend Reached
Pension Benefits
2019
2018
Other Postretirement
Benefits
2019
2018
3.12%
4.00%
4.26%
4.00%
—
—
—
—
—
—
3.21%
—
6.68%
4.50%
2028
4.31%
—
8.48%
4.50%
2026
Assumed health care cost trend rates have a significant effect on the amounts reported for the health care plans. A one-percentage-
point change in assumed health care cost trend rates would have the following effects:
(in millions)
Effect on service and interest components of net periodic cost
Effect on accumulated postretirement benefit obligation
1% point
increase
1% point
decrease
$
1.2
$
30.1
(1.1)
(26.3)
We expect to make contributions of approximately $3.0 million to our pension plans and approximately $24.0 million to our
postretirement medical and life plans in 2020.
The following table provides benefits expected to be paid in each of the next five fiscal years, and in the aggregate for the five
fiscal years thereafter. The expected benefits are estimated based on the same assumptions used to measure our benefit obligation
at the end of the year and include benefits attributable to the estimated future service of employees:
(in millions)
Year(s)
2020
2021
2022
2023
2024
2025-2029
Pension
Benefits
Other
Postretirement
Benefits
Federal
Subsidy
Receipts
$
178.8
$
177.8
175.8
168.5
164.4
723.7
$
38.1
38.6
38.4
38.1
37.9
181.0
0.5
0.4
0.4
0.4
0.4
1.5
93
Table of Contents
NISOURCE INC.
Notes to Consolidated Financial Statements
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (continued)
The following table provides the components of the plans’ actuarially determined net periodic benefits cost for each of the three
years ended December 31, 2019, 2018 and 2017:
(in millions)
Components of Net Periodic Benefit
Cost(1)
Service cost
Interest cost
Expected return on assets
Amortization of prior service cost
(credit)
Recognized actuarial loss
Settlement loss
Pension Benefits
Other Postretirement
Benefits
2019
2018
2017
2019
2018
2017
$
29.2
72.3
(108.8)
0.2
45.2
9.5
$
31.3
$
30.0
$
5.1
$
5.0
$
67.1
(142.3)
(0.4)
40.6
18.5
68.3
(123.1)
(0.7)
52.9
13.7
19.2
(13.1)
(3.2)
2.0
—
17.6
(14.9)
(4.0)
3.8
—
4.8
17.8
(15.9)
(4.4)
3.0
—
5.3
Total Net Periodic Benefits Cost
(1)Service cost is presented in "Operation and maintenance" on the Statements of Consolidated Income (Loss). Non-service cost components are presented
within "Other, net."
41.1
47.6
10.0
14.8
7.5
$
$
$
$
$
$
The following table provides the key assumptions that were used to calculate the net periodic benefits cost for our various plans:
Pension Benefits
2018
2019
2017
Other Postretirement
Benefits
2018
2019
2017
Weighted-average Assumptions to
Determine Net Periodic Benefit Cost
Discount rate - service cost(1)
Discount rate - interest cost(1)
Expected Long-Term Rate of Return on
Plan Assets
Rate of Compensation Increases
4.48%
3.84%
6.10%
4.00%
3.79%
3.15%
7.00%
4.00%
4.40%
3.31%
7.25%
4.00%
4.59%
3.94%
5.83%
—
3.89%
3.27%
5.80%
—
4.58%
3.48%
6.99%
—
(1) In January 2017, we changed the method used to estimate the service and interest components of net periodic benefit cost for pension and other postretirement
benefits. This change, compared to the previous method, resulted in a decrease in the actuarially-determined service and interest cost components. Historically,
we estimated service and interest cost utilizing a single weighted-average discount rate derived from the yield curve used to measure the benefit obligation at the
beginning of the period. For fiscal 2017 and beyond, we now utilize a full yield curve approach to estimate these components by applying the specific spot rates
along the yield curve used in the determination of the benefit obligation to the relevant projected cash flows.
We believe it is appropriate to assume a 6.10% and 5.83% rate of return on pension and other postretirement plan assets, respectively,
for our calculation of 2019 pension benefits cost. These rates are primarily based on asset mix and historical rates of return and
were adjusted in the current year due to anticipated changes in asset allocation and projected market returns.
94
Table of Contents
NISOURCE INC.
Notes to Consolidated Financial Statements
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (continued)
The following table provides other changes in plan assets and projected benefit obligations recognized in other comprehensive
income or regulatory asset or liability:
(in millions)
Other Changes in Plan Assets and Projected Benefit
Obligations Recognized in
Other Comprehensive Income or Regulatory Asset or
Liability
Net prior service cost
Net actuarial loss (gain)
Settlements
Less: amortization of prior service cost
Less: amortization of net actuarial loss
Total Recognized in Other Comprehensive Income or
Regulatory Asset or Liability
Amount Recognized in Net Periodic Benefits Cost and
Other Comprehensive Income or
Regulatory Asset or Liability
$
$
Pension Benefits
Other Postretirement
Benefits
2019
2018
2019
2018
$
— $
0.2
$
5.1
$
(53.8)
(9.5)
(0.2)
(45.2)
127.5
(18.5)
0.4
(40.6)
45.1
—
3.2
(2.0)
(108.7) $
69.0
$
51.4
$
0.1
(5.0)
—
4.0
(3.8)
(4.7)
(61.1) $
83.8
$
61.4
$
2.8
Based on a December 31 measurement date, the estimated net unrecognized actuarial loss, unrecognized prior service cost, and
unrecognized transition obligation that will be amortized into net periodic benefit cost during 2020 for the pension plans are $34.7
million, $0.8 million and zero, respectively, and for other postretirement benefit plans are $4.9 million, $(1.8) million and zero,
respectively.
12.
Equity
We raise equity financing through a variety of programs including traditional common equity issuances and preferred stock
issuances. As of December 31, 2019, we had 600,000,000 shares of common stock and 20,000,000 shares of preferred stock
authorized for issuance, of which 382,135,680 shares of common stock and 440,000 shares of preferred stock are currently
outstanding.
Holders of shares of our common stock are entitled to receive dividends when, as and if declared by the Board out of funds legally
available. The policy of the Board has been to declare cash dividends on a quarterly basis payable on or about the 20th day of
February, May, August and November. We have paid quarterly common dividends totaling $0.80, $0.78, and $0.70 per share for
the years ended December 31, 2019, 2018 and 2017, respectively. Our Board declared a quarterly common dividend of $0.21 per
share, payable on February 20, 2020 to holders of record on February 11, 2020. We have certain debt covenants which could
potentially limit the amount of dividends the Company could pay in order to maintain compliance with these covenants. Refer to
Note 14, "Long-Term Debt," for more information. As of December 31, 2019, these covenants did not restrict the amount of
dividends that were available to be paid.
Dividends paid to preferred shareholders vary based on the series of preferred stock owned. Additional information is provided
below. Holders of our shares of common stock are subject to the prior dividend rights of holders of our preferred stock or the
depositary shares representing such preferred stock outstanding, and if full dividends have not been declared and paid on all
outstanding shares of preferred stock in any dividend period, no dividend may be declared or paid or set aside for payment on our
common stock.
Common and preferred stock activity for 2019, 2018 and 2017 is described further below:
ATM Program and Forward Sale Agreements. On May 3, 2017, we entered into four separate equity distribution agreements,
pursuant to which we were able to sell up to an aggregate of $500.0 million of our common stock.
95
Table of Contents
NISOURCE INC.
Notes to Consolidated Financial Statements
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (continued)
On November 13, 2017, under the ATM program, we executed a forward agreement, which allowed us to issue a fixed number
of shares at a price to be settled in the future. On November 6, 2018, the forward agreement was settled for $26.43 per share,
resulting in $167.7 million of net proceeds. The equity distribution agreements entered into on May 3, 2017 expired December
31, 2018.
On November 1, 2018, we entered into five separate equity distribution agreements pursuant to which we were able to sell up to
an aggregate of $500.0 million of our common stock. Four of these agreements were then amended on August 1, 2019 and one
was terminated, pursuant to which we may sell, from time to time, up to an aggregate of $434.4 million of our common stock.
On December 6, 2018, under the ATM program, we executed a forward agreement, which allowed us to issue a fixed number of
shares at a price to be settled in the future. From December 6, 2018 to December 10, 2018, 4,708,098 shares were borrowed from
third parties and sold by the dealer at a weighted average price of $26.55 per share. On November 21, 2019, the forward agreement
was settled for $26.01 per share, resulting in $122.5 million of net proceeds.
On August 12, 2019, under the ATM program, we executed a separate forward agreement, which allowed us to issue a fixed number
of shares at a price to be settled in the future. From August 12, 2019 to September 13, 2019, 3,714,400 shares were borrowed from
third parties and sold by the dealer at a weighted average price of $29.26 per share. On December 11, 2019, the forward agreement
was settled for $28.83 per share, resulting in $107.1 million of net proceeds.
As of December 31, 2019, the ATM program had approximately $200.7 million of equity available for issuance. The program
expires on December 31, 2020.
The following table summarizes our activity under the ATM program:
Year Ending December 31,
Number of shares issued
Average price per share
Proceeds, net of fees (in millions)
2019
2018
2017
8,422,498
8,883,014
11,931,376
$
$
27.75
229.1
$
$
26.85
232.5
$
$
26.58
314.7
Private Placement of Common Stock. On May 4, 2018, we completed the sale of 24,964,163 shares of $0.01 par value common
stock at a price of $24.28 per share in a private placement to selected institutional and accredited investors. The private placement
resulted in $606.0 million of gross proceeds or $599.6 million of net proceeds, after deducting commissions and sale expenses.
The common stock issued in connection with the private placement was registered on Form S-1, filed with the SEC on May 11,
2018.
Preferred Stock. On June 11, 2018, we completed the sale of 400,000 shares of 5.650% Series A Fixed-Rate Reset Cumulative
Redeemable Perpetual Preferred Stock (the "Series A Preferred Stock") at a price of $1,000 per share. The transaction resulted in
$400.0 million of gross proceeds or $393.9 million of net proceeds, after deducting commissions and sale expenses. The Series
A Preferred Stock was issued in a private placement pursuant to SEC Rule 144A. On December 13, 2018, we filed a registration
statement with the SEC enabling holders to exchange their unregistered shares of Series A Preferred Stock for publicly registered
shares with substantially identical terms.
Proceeds from the issuance of the Series A Preferred Stock were used to pay a portion of the notes tendered in June 2018 and the
redemption of the remaining notes in July 2018. See Note 14, “Long-term Debt” for additional information regarding the tender
offer and redemption.
Dividends on the Series A Preferred Stock accrue and are cumulative from the date the shares of Series A Preferred Stock were
originally issued to, but not including, June 15, 2023 at a rate of 5.650% per annum of the $1,000 liquidation preference per share.
On and after June 15, 2023, dividends on the Series A Preferred Stock will accumulate for each five year period at a percentage
of the $1,000 liquidation preference equal to the five-year U.S. Treasury Rate plus (i) in respect of each five year period commencing
on or after June 15, 2023 but before June 15, 2043, a spread of 2.843% (the “Initial Margin”), and (ii) in respect of each five year
period commencing on or after June 15, 2043, the Initial Margin plus 1.000%. The Series A Preferred Stock may be redeemed by
us at our option on June 15, 2023, or on each date falling on the fifth anniversary thereafter, or in connection with a ratings event
(as defined in the Certificate of Designation of the Series A Preferred Stock).
As of December 31, 2019 and 2018, Series A Preferred Stock had $1.0 million of cumulative preferred dividends in arrears, or
$2.51 per share.
96
Table of Contents
NISOURCE INC.
Notes to Consolidated Financial Statements
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (continued)
Holders of Series A Preferred Stock generally have no voting rights, except for limited voting rights with respect to (i) potential
amendments to our certificate of incorporation that would have a material adverse effect on the existing preferences, rights, powers
or duties of the Series A Preferred Stock, (ii) the creation or issuance of any security ranking on a parity with the Series A Preferred
Stock if the cumulative dividends payable on then outstanding Series A Preferred Stock are in arrears, or (iii) the creation or
issuance of any security ranking senior to the Series A Preferred Stock. The Series A Preferred Stock does not have a stated maturity
and is not subject to mandatory redemption or any sinking fund. The Series A Preferred Stock will remain outstanding indefinitely
unless repurchased or redeemed by us. Any such redemption would be effected only out of funds legally available for such purposes
and will be subject to compliance with the provisions of our outstanding indebtedness.
On December 5, 2018, we completed the sale of 20,000,000 depositary shares with an aggregate liquidation preference of
$500,000,000 under the Company’s registration statement on Form S-3. Each depositary share represents 1/1,000th ownership
interest in a share of our 6.500% Series B Fixed-Rate Reset Cumulative Redeemable Perpetual Preferred Stock, liquidation
preference $25,000 per share (equivalent to $25 per depositary share) (the “Series B Preferred Stock"). The transaction resulted
in $500.0 million of gross proceeds or $486.1 million of net proceeds, after deducting commissions and sale expenses.
Dividends on the Series B Preferred Stock accrue and are cumulative from the date the shares of Series B Preferred Stock were
originally issued to, but not including, March 15, 2024 at a rate of 6.500% per annum of the $25,000 liquidation preference per
share. On and after March 15, 2024, dividends on the Series B Preferred Stock will accumulate for each five year period at a
percentage of the $25,000 liquidation preference equal to the five-year U.S. Treasury Rate plus (i) in respect of each five year
period commencing on or after March 15, 2024 but before March 15, 2044, a spread of 3.632% (the “Initial Margin”), and (ii) in
respect of each five year period commencing on or after March 15, 2044, the Initial Margin plus 1.000%. The Series B Preferred
Stock may be redeemed by us at our option on March 15, 2024, or on each date falling on the fifth anniversary thereafter, or in
connection with a ratings event (as defined in the Certificate of Designation of the Series B Preferred Stock).
As of December 31, 2019 and 2018, Series B Preferred Stock had $1.4 million and $2.4 million, respectively, of cumulative
preferred dividends in arrears, or $72.23 and $121.88 per share, respectively.
In addition, we issued 20,000 shares of “Series B-1 Preferred Stock”, par value $0.01 per share, (“Series B-1 Preferred Stock”),
as a distribution with respect to the Series B Preferred Stock. As a result, each of the depositary shares issued on December 5,
2018 now represents a 1/1,000th ownership interest in a share of Series B Preferred Stock and a 1/1,000th ownership interest in
a share of Series B-1 Preferred Stock. We issued the Series B-1 Preferred Stock to enhance the voting rights of the Series B
Preferred Stock to comply with the minimum voting rights policy of the New York Stock Exchange. The Series B-1 Preferred
Stock is paired with the Series B Preferred Stock and may not be transferred, redeemed or repurchased except in connection with
the simultaneous transfer, redemption or repurchase of a like number of shares of the underlying Series B Preferred Stock.
Holders of Series B Preferred Stock generally have no voting rights, except for limited voting rights with respect to (i) potential
amendments to our certificate of incorporation that would have a material adverse effect on the existing preferences, rights, powers
or duties of the Series B Preferred Stock, (ii) the creation or issuance of any security ranking on a parity with the Series B Preferred
Stock if the cumulative dividends payable on then outstanding Series B Preferred Stock are in arrears, or (iii) the creation or
issuance of any security ranking senior to the Series B Preferred Stock. In addition, if and whenever dividends on any shares of
Series B Preferred Stock shall not have been declared and paid for at least six dividend periods, whether or not consecutive, the
number of directors then constituting our Board of Directors shall automatically be increased by two until all accumulated and
unpaid dividends on the Series B Preferred Stock shall have been paid in full, and the holders of Series B-1 Preferred Stock, voting
as a class together with the holders of any outstanding securities ranking on a parity with the Series B-1 Preferred Stock and having
like voting rights that are exercisable at the time and entitled to vote thereon, shall be entitled to elect the two additional directors.
The Series B Preferred Stock does not have a stated maturity and is not subject to mandatory redemption or any sinking fund. The
Series B Preferred Stock will remain outstanding indefinitely unless repurchased or redeemed by us. Any such redemption would
be effected only out of funds legally available for such purposes and will be subject to compliance with the provisions of our
outstanding indebtedness.
97
Table of Contents
NISOURCE INC.
Notes to Consolidated Financial Statements
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (continued)
The following table summarizes preferred stock by outstanding series of shares:
Year ended December 31,
December 31, December 31,
2019
2018
2017
2019
2018
(in millions except shares
and per share amounts)
5.650% Series A
6.500% Series B
$
$
Liquidation
Preference Per
Share
Shares
Dividends Declared Per Share
Outstanding
1,000.00 400,000 $
56.50 $
28.88 $
25,000.00
20,000 $ 1,674.65 $
— $
— $
— $
393.9
486.1
$
$
393.9
486.1
13.
Share-Based Compensation
Our stockholders most recently approved the NiSource Inc. 2010 Omnibus Incentive Plan (“Omnibus Plan”) at the Annual Meeting
of Stockholders held on May 12, 2015. The Omnibus Plan provides for awards to employees and non-employee directors of
incentive and nonqualified stock options, stock appreciation rights, restricted stock, restricted stock units, performance shares,
performance units, cash-based awards and other stock-based awards and supersedes the long-term incentive plan approved by
stockholders on April 13, 1994 (“1994 Plan”) and the Director Stock Incentive Plan (“Director Plan”). The Omnibus Plan provides
that the number of shares of common stock of NiSource available for awards is 8,000,000 plus the number of shares subject to
outstanding awards that expire or terminate for any reason that were granted under either the 1994 Plan or the Director Plan, plus
the number of shares that were awarded as a result of the Separation-related adjustments. At December 31, 2019, there were
3,313,183 shares reserved for future awards under the Omnibus Plan.
We recognized stock-based employee compensation expense of $16.3 million, $15.2 million and $15.3 million, during 2019, 2018
and 2017, respectively, as well as related tax benefits of $4.0 million, $3.7 million and $5.9 million, respectively. We recognized
related excess tax benefits from the distribution of vested share-based employee compensation of $0.8 million, $1.0 million and
$4.4 million in 2019, 2018 and 2017, respectively.
As of December 31, 2019, the total remaining unrecognized compensation cost related to non-vested awards amounted to $19.5
million, which will be amortized over the weighted-average remaining requisite service period of 1.8 years.
Restricted Stock Units and Restricted Stock. In 2019, we granted 166,031 restricted stock units and shares of restricted stock to
employees, subject to service conditions. The total grant date fair value of the restricted stock units and shares of restricted stock
was $4.1 million, based on the average market price of our common stock at the date of each grant less the present value of any
dividends not received during the vesting period, which will be expensed over the vesting period which is generally three years.
As of December 31, 2019, 157,786 non-vested restricted stock units and shares of restricted stock granted in 2019 were outstanding
as of December 31, 2019.
In 2018, we granted 158,689 restricted stock units and shares of restricted stock to employees, subject to service conditions. The
total grant date fair value of the restricted stock units and shares of restricted stock was $3.5 million, based on the average market
price of our common stock at the date of each grant less the present value of any dividends not received during the vesting period,
which will be expensed over the vesting period which is generally three years. As of December 31, 2019, 136,820 non-vested
restricted stock units and shares of restricted stock granted in 2018 were outstanding as of December 31, 2019.
Restricted stock units and shares of restricted stock granted to employees in 2017 were immaterial.
If an employee terminates employment before the service conditions lapse under the 2017, 2018 or 2019 awards due to (1) retirement
or disability (as defined in the award agreement), or (2) death, the service conditions will lapse on the date of such termination
with respect to a pro rata portion of the restricted stock units and shares of restricted stock based upon the percentage of the service
period satisfied between the grant date and the date of the termination of employment. In the event of a change in control (as
defined in the award agreement), all unvested shares of restricted stock and restricted stock units awarded will immediately vest
upon termination of employment occurring in connection with a change in control. Termination due to any other reason will result
in all unvested shares of restricted stock and restricted stock units awarded being forfeited effective on the employee’s date of
termination.
98
Table of Contents
NISOURCE INC.
Notes to Consolidated Financial Statements
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (continued)
(shares)
Non-vested at December 31, 2018
Granted
Forfeited
Vested
Non-vested at December 31, 2019
Restricted Stock
Units
Weighted Average
Award Date Fair
Value Per Unit ($)
178,678
166,031
(21,547)
(20,556)
302,606
21.82
24.93
22.99
21.08
23.49
Performance Shares. In 2019, we granted 552,389 performance shares subject to service, performance and market conditions.
The service conditions for these awards lapse on February 28, 2022. The performance period for the awards is the period beginning
January 1, 2019 and ending December 31, 2021. The performance conditions are based on the achievement of one non-GAAP
financial measure and additional operational measures as outlined below.
The financial measure is cumulative net operating earnings per share ("NOEPS"), which we define as income from continuing
operations adjusted for certain unusual or non-recurring items. The number of cumulative NOEPS shares determined using this
measure shall be increased or decreased based on our relative total shareholder return, a market condition which we define as the
annualized growth in dividends and share price of a share of our common stock (calculated using a 20 trading day average of our
closing price beginning on December 31, 2018 and ending on December 31, 2021) compared to the total shareholder return of a
predetermined peer group of companies. A relative shareholder return result within the first quartile will result in an increase to
the NOEPS shares of 25%, while a relative shareholder return result within the fourth quartile will result in a decrease of 25%. A
Monte Carlo analysis was used to value the portion of these awards dependent on market conditions. The grant date fair value of
the awards was $11.7 million, based on the average market price of our common stock at the date of each grant less the present
value of dividends not received during the vesting period which will be expensed over the requisite service period of three years.
As of December 31, 2019, 422,825 of these non-vested performance shares granted in 2019 remained outstanding.
If a threshold level of cumulative NOEPS financial performance is achieved, additional operational measures which we refer to
as the customer value index, which consists of five equally weighted areas of focus including safety, customer satisfaction, financial,
culture and environmental apply. Each area of focus represents 20% of the customer value index shares, and the targets for all
areas must be met for these awards to be eligible for 100% payout of these awards. The grant date fair value of the awards was
$2.5 million, based on the average market price of our common stock on the grant date of each award less the present value of
dividends not received during the vesting period which will be expensed over the requisite service period of three years. As of
December 31, 2019, 97,574 of these awards that were issued in 2019 remained outstanding.
In 2018, we awarded 514,338 performance shares subject to service, performance and market conditions. The service conditions
for these awards lapse on February 26, 2021. The performance period for the awards is the period beginning January 1, 2018 and
ending December 31, 2020. The performance conditions are based on the achievement of one non-GAAP financial measure and
additional operational measures as outlined below.
The financial measure is cumulative net operating earnings per share ("NOEPS"), which we define as income from continuing
operations adjusted for certain unusual or non-recurring items. The number of cumulative NOEPS shares determined using this
measure shall be increased or decreased based on our relative total shareholder return, a market condition which we define as the
annualized growth in dividends and share price of a share of our common stock (calculated using a 20 trading day average of our
closing price beginning on December 31, 2017 and ending on December 31, 2020) compared to the total shareholder return of a
predetermined peer group of companies. A relative shareholder return result within the first quartile will result in an increase to
the NOEPS shares of 25% while a relative shareholder return result within the fourth quartile will result in a decrease of 25%. A
Monte Carlo analysis was used to value the portion of these awards dependent on market conditions. The grant date fair value of
the awards was $9.2 million, based on the average market price of our common stock at the date of each grant less the present
value of dividends not received during the vesting period which will be expensed over the requisite service period of three years.
As of December 31, 2019, 368,811 of these non-vested performance shares granted in 2018 remained outstanding.
If a threshold level of cumulative NOEPS financial performance is achieved, additional operational measures which we refer to
as the customer value index, which consists of five equally weighted areas of focus including safety, customer satisfaction, financial,
culture and environmental apply. Each area of focus represents 20% of the customer value index shares and the targets for all areas
must be met for these awards to be eligible for 100% payout of these awards. Individual payout percentages for these shares may
99
Table of Contents
NISOURCE INC.
Notes to Consolidated Financial Statements
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (continued)
range from 0%-200% as determined by the compensation committee in its sole discretion. Due to this discretion, these shares are
not considered to be granted under ASC 718. The service inception date fair value of the awards was $2.4 million, based on the
closing market price of our common stock on the service inception date of each award. This value will be reassessed at each
reporting period to be based on our closing market price of our common stock at the reporting period date with adjustments to
expense recorded as appropriate. As of December 31, 2019, 85,111 of these awards that were issued in 2018 remained outstanding.
The service conditions for these awards lapse on February 26, 2021.
In 2017, we granted 660,750 performance shares subject to service, performance and market conditions. The grant date fair value
of the awards was $12.9 million, based on the average market price of our common stock at the date of each grant less the present
value of dividends not received during the vesting period which will be expensed over the requisite service period of three years.
The performance conditions are based on achievement of non-GAAP financial measures similar to those discussed above:
cumulative net operating earnings per share for the three-year period ending December 31, 2019 and relative total shareholder
return (calculated using a 20 trading day average of our closing price beginning on December 31, 2016 and ending on December
31, 2019). As of December 31, 2019, 528,928 non-vested performance shares granted in 2017 remained outstanding. The service
conditions for these awards lapse on February 28, 2020.
(shares)
Non-vested at December 31, 2018
Granted
Forfeited
Vested
Performance
Awards
1,634,718
Weighted Average
Grant Date Fair
Value Per Unit ($)(1)
20.45
552,389
(156,700)
(527,156)
1,503,251
25.77
26.72
28.11
22.74
Non-vested at December 31, 2019
(1)2018 performance shares awarded based on the customer value index are included at reporting date fair value as these awards have not been granted under
ASC 718 as discussed above.
Non-employee Director Awards. As of May 11, 2010, awards to non-employee directors may be made only under the Omnibus
Plan. Currently, restricted stock units are granted annually to non-employee directors, subject to a non-employee director’s election
to defer receipt of such restricted stock unit award. The non-employee director’s annual award of restricted stock units vest on the
first anniversary of the grant date subject to special pro-rata vesting rules in the event of retirement or disability (as defined in the
award agreement), or death. The vested restricted stock units are payable as soon as practicable following vesting except as
otherwise provided pursuant to the non-employee director’s election to defer. Certain restricted stock units remain outstanding
from the Director Plan. All such awards are fully vested and shall be distributed to the directors upon their separation from the
Board.
As of December 31, 2019, 165,768 restricted stock units are outstanding to non-employee directors under either the Omnibus Plan
or the Director Plan. Of this amount, 49,926 restricted stock units are unvested and expected to vest.
401(k) Match, Profit Sharing and Company Contribution. We have a voluntary 401(k) savings plan covering eligible employees
that allows for periodic discretionary matches as a percentage of each participant’s contributions payable in cash for nonunion
employees and generally payable in shares of NiSource common stock for union employees, subject to collective bargaining. We
also have a retirement savings plan that provides for discretionary profit sharing contributions similarly payable in cash or shares
of NiSource common stock to eligible employees based on earnings results, and eligible employees hired after January 1, 2010
receive a non-elective company contribution of 3% of eligible pay similarly payable in cash or shares of NiSource common stock.
For the years ended December 31, 2019, 2018 and 2017, we recognized 401(k) match, profit sharing and non-elective contribution
expense of $37.5 million, $37.6 million and $37.6 million, respectively.
100
Table of Contents
NISOURCE INC.
Notes to Consolidated Financial Statements
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (continued)
14.
Long-Term Debt
Our long-term debt as of December 31, 2019 and 2018 is as follows:
Long-term debt type
Senior notes:
NiSource
NiSource
NiSource
NiSource
NiSource
NiSource
NiSource
NiSource
NiSource
NiSource
NiSource
NiSource
NiSource
NiSource
NiSource
NiSource
Total senior notes
Medium term notes:
NiSource
NIPSCO
Columbia of Massachusetts
Total medium term notes
Finance leases:
NiSource Corporate Services
Columbia of Ohio
Columbia of Virginia
Columbia of Kentucky
Columbia of Pennsylvania
Columbia of Massachusetts
Total finance leases
Pollution control bonds - NIPSCO
Unamortized issuance costs and discounts
Total Long-Term Debt
Maturity as of December 31,
2019
Weighted
average
interest rate
(%)
Outstanding balance
as of December 31,
(in millions)
2019
2018
December 2021
November 2022
February 2023
June 2023
November 2025
May 2027
December 2027
September 2029
December 2040
June 2041
February 2042
February 2043
February 2044
February 2045
May 2047
March 2048
April 2022 to May 2027
August 2022 to August 2027
December 2025 to February 2028
January 2020 to November 2023
October 2021 to March 2044
July 2029 to November 2039
May 2027
August 2027 to May 2035
December 2033 to November 2043
April 2019
4.45%
2.65%
3.85%
3.65%
5.89%
3.49%
6.78%
2.95%
6.25%
5.95%
5.80%
5.25%
4.80%
5.65%
4.38%
3.95%
7.99%
7.61%
6.30%
3.47%
6.16%
6.31%
3.79%
5.67%
5.49%
5.85%
63.6
500.0
250.0
350.0
265.0
1,000.0
3.0
750.0
250.0
400.0
250.0
500.0
750.0
500.0
1,000.0
750.0
$7,581.6
63.6
500.0
250.0
350.0
265.0
1,000.0
3.0
—
250.0
400.0
250.0
500.0
750.0
500.0
1,000.0
750.0
$6,831.6
$
49.0
68.0
40.0
$ 157.0
$
49.0
68.0
40.0
$ 157.0
22.3
94.8
19.1
0.3
20.7
11.6
91.5
15.2
0.3
30.0
44.3
201.5
—
45.7
194.3
41.0
(70.5) $ (68.5)
$7,869.6
$7,155.4
Details of our 2019 long-term debt related activity are summarized below:
• On April 1, 2019, NIPSCO repaid $41.0 million of 5.85% pollution control bonds at maturity.
• On August 12, 2019, we closed our placement of $750.0 million of 2.95% senior unsecured notes maturing in 2029 which
resulted in approximately $742.4 million of net proceeds after deducting commissions and expenses.
101
Table of Contents
NISOURCE INC.
Notes to Consolidated Financial Statements
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (continued)
Details of our 2018 long-term debt related activity are summarized below:
• On March 15, 2018, we redeemed $275.1 million of 6.40% senior unsecured notes at maturity.
•
In June 2018, we executed a tender offer for $209.0 million of outstanding notes consisting of a combination of our 6.80%
notes due 2019, 5.45% notes due 2020, and 6.125% notes due 2022. In conjunction with the debt retired, we recorded a
$12.5 million loss on early extinguishment of long-term debt, primarily attributable to early redemption premiums.
• On June 11, 2018, we closed our private placement of $350.0 million of 3.65% senior unsecured notes maturing in 2023
which resulted in approximately $346.6 million of net proceeds after deducting commissions and expenses. We used the
net proceeds from this private placement to pay a portion of the redemption price for the notes subject to the tender offer
described above.
•
In July 2018, we redeemed $551.1 million of outstanding notes representing the remainder of our 6.80% notes due 2019,
5.45% notes due 2020 and 6.125% notes due 2022. During the third quarter of 2018, we recorded a $33.0 million loss
on early extinguishment of long-term debt, primarily attributable to early redemption premiums.
See Note 19-A, "Contractual Obligations," for the outstanding long-term debt maturities at December 31, 2019.
Unamortized debt expense, premium and discount on long-term debt applicable to outstanding bonds are being amortized over
the life of such bonds.
We are subject to a financial covenant under our revolving credit facility and term loan agreement which requires us to maintain
a debt to capitalization ratio that does not exceed 70%. A similar covenant in a 2005 private placement note purchase agreement
requires us to maintain a debt to capitalization ratio that does not exceed 75%. As of December 31, 2019, the ratio was 61.7%.
We are also subject to certain other non-financial covenants under the revolving credit facility. Such covenants include a limitation
on the creation or existence of new liens on our assets, generally exempting liens on utility assets, purchase money security interests,
preexisting security interests and an additional subset of assets equal to $150 million. An asset sale covenant generally restricts
the sale, conveyance, lease, transfer or other disposition of our assets to those dispositions that are for a price not materially less
than fair market of such assets, that would not materially impair our ability to perform obligations under the revolving credit
facility, and that together with all other such dispositions, would not have a material adverse effect. The covenant also restricts
dispositions to no more than 10% of our consolidated total assets on December 31, 2015. The revolving credit facility also includes
a cross-default provision, which triggers an event of default under the credit facility in the event of an uncured payment default
relating to any indebtedness of us or any of our subsidiaries in a principal amount of $50.0 million or more.
Our indentures generally do not contain any financial maintenance covenants. However, our indentures are generally subject to
cross-default provisions ranging from uncured payment defaults of $5 million to $50 million, and limitations on the incurrence
of liens on our assets, generally exempting liens on utility assets, purchase money security interests, preexisting security interests
and an additional subset of assets capped at 10% of our consolidated net tangible assets.
15.
Short-Term Borrowings
We generate short-term borrowings from our revolving credit facility, commercial paper program, accounts receivable transfer
programs and term loan borrowings. Each of these borrowing sources is described further below.
We maintain a revolving credit facility to fund ongoing working capital requirements, including the provision of liquidity support
for our commercial paper program, provide for issuance of letters of credit and also for general corporate purposes. Our revolving
credit facility has a program limit of $1.85 billion and is comprised of a syndicate of banks led by Barclays. On February 20, 2019,
we extended the termination date of our revolving credit facility to February 20, 2024. At December 31, 2019 and 2018, we had
no outstanding borrowings under this facility.
Our commercial paper program has a program limit of up to $1.5 billion with a dealer group comprised of Barclays, Citigroup,
Credit Suisse and Wells Fargo. We had $570.0 million and $978.0 million of commercial paper outstanding as of December 31,
2019 and 2018, respectively.
Transfers of accounts receivable are accounted for as secured borrowings resulting in the recognition of short-term borrowings on
the Consolidated Balance Sheets. We had $353.2 million and $399.2 million in transfers as of December 31, 2019 and 2018,
respectively. Refer to Note 18, "Transfers of Financial Assets," for additional information.
102
Table of Contents
NISOURCE INC.
Notes to Consolidated Financial Statements
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (continued)
On April 17, 2019, we amended our existing term loan agreement with a syndicate of banks, with MUFG Bank Ltd. as the
Administrative Agent, Sole Lead Arranger and Sole Bookrunner. The amendment increased the amount of our term loan from
$600.0 million to $850.0 million and extended the maturity date to April 16, 2020. Interest charged on borrowings depends on the
variable rate structure we elect at the time of each borrowing. The available variable rate structures from which we may choose
are defined in the term loan agreement. Under the agreement, we borrowed $850.0 million on April 17, 2019 with an interest rate
of LIBOR plus 60 basis points.
Short-term borrowings were as follows:
At December 31, (in millions)
Commercial Paper weighted-average interest rate of 2.03% and 2.96% at December 31, 2019
and 2018, respectively
Accounts receivable securitization facility borrowings
Term loan weighted-average interest rate of 2.40% and 3.07% at December 31, 2019 and
2018, respectively
Total Short-Term Borrowings
$
$
2019
2018
570.0
353.2
850.0
1,773.2
$
$
$
978.0
399.2
600.0
1,977.2
Other than for the term loan and certain commercial paper borrowings, cash flows related to the borrowings and repayments of
the items listed above are presented net in the Statements of Consolidated Cash Flows as their maturities are less than 90 days.
16.
Leases
ASC 842 Adoption. In February 2016, the FASB issued ASU 2016-02, Leases (ASC 842). ASU 2016-02 introduces a lessee model
that brings most leases onto the balance sheet. The standard requires that lessees recognize the following for all leases (with the
exception of short-term leases, as that term is defined in the standard) at the lease commencement date: (1) a lease liability, which
is a lessee’s obligation to make lease payments arising from a lease, measured on a discounted basis; and (2) a right-of-use asset,
which is an asset that represents the lessee’s right to use, or control the use of, a specified asset for the lease term. In 2018, the
FASB issued ASU 2018-01, Leases (ASC 842): Land Easement Practical Expedient for Transition to ASC 842, which allows us
to not evaluate existing land easements under ASC 842, and ASU 2018-11, Leases (ASC 842): Targeted Improvements, which
allows calendar year entities to initially apply ASC 842 prospectively from January 1, 2019.
We adopted the provisions of ASC 842 beginning on January 1, 2019, using the transition method provided in ASU 2018-11, which
was applied to all existing leases at that date. As such, results for reporting periods beginning after January 1, 2019 will be presented
under ASC 842, while prior period amounts will continue to be reported in accordance with ASC 840. We elected a number of
practical expedients, including the "practical expedient package" described in ASC 842-10-65-1 and the provisions of ASU 2018-01,
which allows us to not evaluate existing land easements under ASC 842. Further, ASC 842 provides lessees the option of electing
an accounting policy, by class of underlying asset, in which the lessee may choose not to separate nonlease components from lease
components. We elected this practical expedient for our leases of fleet vehicles, IT assets and railcars. We elected to use a practical
expedient that allows the use of hindsight in determining lease terms when evaluating leases that existed at the implementation
date. We also elected the short-term lease recognition exemption, allowing us to not recognize ROU assets or lease liabilities for
all leases that qualify.
Adoption of the new standard resulted in the recording of additional lease liabilities and corresponding ROU assets of $57.0 million
on our Consolidated Balance Sheets as of January 1, 2019. The standard had no material impact on our Statements of Consolidated
Income (Loss) or our Statements of Consolidated Cash Flows.
Lease Descriptions. We are the lessee for substantially all of our leasing activity, which includes operating and finance leases for
corporate and field offices, railcars, fleet vehicles and certain IT assets. Our corporate and field office leases have remaining lease
terms between 1 and 24 years with options to renew the leases for up to 25 years. We lease railcars to transport coal to and from
our electric generation facilities in Indiana. Our railcars are specifically identified in the lease agreements and have lease terms
between 1 and 3 years with options to renew for 1 year. Our fleet vehicles include trucks, trailers and equipment that have been
customized specifically for use in the utility industry. We lease fleet vehicles on 1 year terms, after which we have the option to
extend on a month-to-month basis or terminate with written notice. ROU assets and liabilities on our Consolidated Balance Sheets
do not include obligations for possible fleet vehicle lease renewals beyond the initial lease term. While we have the ability to renew
these leases beyond the initial term, we are not reasonably certain (as that term is defined in ASC 842) to do so. We lease the
majority of our IT assets under 4 year lease terms. Ownership of leased IT assets is transferred to us at the end of the lease term.
103
Table of Contents
NISOURCE INC.
Notes to Consolidated Financial Statements
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (continued)
We have not provided material residual value guarantees for our leases, nor do our leases contain material restrictions or covenants.
Lease contracts containing renewal and termination options are mostly exercisable at our sole discretion. Certain of our real estate
and railcar leases include renewal periods in the measurement of the lease obligation if we have deemed the renewals reasonably
certain to be exercised.
With respect to service contracts involving the use of assets, if we have the right to direct the use of the asset and obtain substantially
all economic benefits from the use of an asset, we account for the service contract as a lease. Unless specifically provided to us
by the lessor, we utilize NiSource's collateralized incremental borrowing rate commensurate to the lease term as the discount rate
for all of our leases.
Lease costs for the year ended December 31, 2019 are presented in the table below. These costs include both amounts recognized
in expense and amounts capitalized as part of the cost of another asset. Income statement presentation for these costs (when
ultimately recognized on the income statement) is also included:
Year Ended December 31, (in millions)
Finance lease cost
Income Statement Classification
2019
Amortization of right-of-use assets
Interest on lease liabilities
Depreciation and amortization
Interest expense, net
Total finance lease cost
Operating lease cost
Short-term lease cost
Total lease cost
Operation and maintenance
Operation and maintenance
$
$
15.5
11.3
26.8
17.9
1.0
45.7
Our right-of-use assets and liabilities are presented in the following lines on the Consolidated Balance Sheets:
(in millions)
Assets
Finance leases
Operating leases
Total leased assets
Liabilities
Current
Finance leases
Operating leases
Noncurrent
Finance leases
Operating leases
Total lease liabilities
Balance Sheet Classification
December 31, 2019
Net Property, Plant and Equipment
Deferred charges and other
Current portion of long-term debt
Other accruals
Long-term debt, excluding amounts due within one year
Other noncurrent liabilities
$
$
179.5
64.2
243.7
13.4
13.2
188.1
51.6
266.3
104
Table of Contents
NISOURCE INC.
Notes to Consolidated Financial Statements
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (continued)
Other pertinent information related to leases was as follows:
Year Ended December 31, (in millions)
Cash paid for amounts included in the measurement of lease liabilities
Operating cash flows used for finance leases
Operating cash flows used for operating leases
Financing cash flows used for finance leases
Right-of-use assets obtained in exchange for lease obligations
Finance leases
Operating leases
Weighted-average remaining lease term (years)
Finance leases
Operating leases
Weighted-average discount rate
Finance leases
Operating leases
Maturities of our lease liabilities presented on a rolling 12-month basis were as follows:
2019
11.3
17.9
10.6
26.4
13.4
$
$
December 31, 2019
14.8
9.2
5.9%
4.3%
Total
Finance Leases
As of December 31, 2019, (in millions)
Year 1
Year 2
Year 3
Year 4
Year 5
Thereafter
Total lease payments(1)
Less: Imputed interest
Less: Leases not yet commenced
Total
Reported as of December 31, 2019
Short-term lease liabilities
Long-term lease liabilities
Total lease liabilities
$
$
42.8 $
36.7
35.0
30.7
26.5
233.3
405.0
(116.6)
(22.1)
266.3
26.6
239.7
266.3 $
Operating Leases
15.6
9.4
8.2
7.6
6.6
31.7
79.1
(14.3)
—
64.8
27.2 $
27.3
26.8
23.1
19.9
201.6
325.9
(102.3)
(22.1)
201.5
13.4
188.1
201.5 $
13.2
51.6
64.8
(1) Expected payments include obligations for leases not yet commenced of approximately $22.1 million for IT assets and interconnection facilities. These leases
have terms between 4 years and 20 years, with estimated commencements in the first quarter of 2020 and in the third quarter of 2020.
105
Table of Contents
NISOURCE INC.
Notes to Consolidated Financial Statements
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (continued)
Disclosures Related to Periods Prior to Adoption of ASC 842.We lease assets in several areas of our operations including fleet
vehicles and equipment, rail cars for coal delivery and certain operations centers. Payments made in connection with operating
leases were $49.1 million in 2018 and $49.5 million in 2017, and are primarily charged to operation and maintenance expense as
incurred.
As of December 31, 2018, total contractual obligations for capital and operating leases were as follows:
As of December 31, 2018, (in millions)
2019
2020
2021
2022
2023
Thereafter
Total lease payments
Total
Capital Leases(1) Operating Leases(2)
11.0
7.3
6.1
4.2
2.8
14.5
45.9
23.0 $
22.5
22.6
22.1
19.8
212.4
322.4 $
34.0 $
29.8
28.7
26.3
22.6
226.9
368.3 $
$
$
(1)Capital lease payments shown above are inclusive of interest totaling $114.6 million.
(2)Operating lease balances do not include obligations for possible fleet vehicle lease renewals beyond the initial lease term. While we have the ability to renew
these leases beyond the initial term, we are not reasonably certain to do so. Expected payments are $26.7 million in 2019, $22.4 million in 2020, $16.6 million in
2021, $12.3 million in 2022, $9.3 million in 2023 and $8.8 million thereafter.
17.
Fair Value
A. Fair Value Measurements
Recurring Fair Value Measurements. The following tables present financial assets and liabilities measured and recorded at fair
value on our Consolidated Balance Sheets on a recurring basis and their level within the fair value hierarchy as of December 31,
2019 and December 31, 2018:
Recurring Fair Value Measurements
December 31, 2019 (in millions)
Assets
Risk management assets
Available-for-sale securities
Total
Liabilities
Risk management liabilities
Total
Quoted Prices
in Active
Markets
for Identical
Assets
(Level 1)
Significant
Other
Observable
Inputs
(Level 2)
Significant
Unobservable
Inputs
(Level 3)
Balance as of
December 31, 2019
$
$
$
$
— $
—
— $
— $
— $
4.4
154.2
158.6
146.6
146.6
$
$
$
$
— $
—
— $
— $
— $
4.4
154.2
158.6
146.6
146.6
106
Table of Contents
NISOURCE INC.
Notes to Consolidated Financial Statements
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (continued)
Recurring Fair Value Measurements
December 31, 2018 (in millions)
Assets
Risk management assets
Available-for-sale securities
Total
Liabilities
Risk management liabilities
Total
Quoted Prices
in Active
Markets
for Identical
Assets
(Level 1)
Significant
Other
Observable
Inputs
(Level 2)
Significant
Unobservable
Inputs
(Level 3)
Balance as of
December 31, 2018
$
$
$
$
— $
—
— $
— $
— $
24.0
138.3
162.3
51.7
51.7
$
$
$
$
— $
—
— $
— $
— $
24.0
138.3
162.3
51.7
51.7
Risk management assets and liabilities include interest rate swaps, exchange-traded NYMEX futures and NYMEX options and
non-exchange-based forward purchase contracts. When utilized, exchange-traded derivative contracts are based on unadjusted
quoted prices in active markets and are classified within Level 1. These financial assets and liabilities are secured with cash on
deposit with the exchange; therefore, nonperformance risk has not been incorporated into these valuations. Certain non-exchange-
traded derivatives are valued using broker or over-the-counter, on-line exchanges. In such cases, these non-exchange-traded
derivatives are classified within Level 2. Non-exchange-based derivative instruments include swaps, forwards, and options. In
certain instances, these instruments may utilize models to measure fair value. We use a similar model to value similar instruments.
Valuation models utilize various inputs that include quoted prices for similar assets or liabilities in active markets, quoted prices
for identical or similar assets or liabilities in markets that are not active, other observable inputs for the asset or liability and market-
corroborated inputs, (i.e., inputs derived principally from or corroborated by observable market data by correlation or other means).
Where observable inputs are available for substantially the full term of the asset or liability, the instrument is categorized within
Level 2. Certain derivatives trade in less active markets with a lower availability of pricing information and models may be utilized
in the valuation. When such inputs have a significant impact on the measurement of fair value, the instrument is categorized within
Level 3. Credit risk is considered in the fair value calculation of derivative instruments that are not exchange-traded. Credit
exposures are adjusted to reflect collateral agreements which reduce exposures. As of December 31, 2019 and 2018, there were
no material transfers between fair value hierarchies. Additionally, there were no changes in the method or significant assumptions
used to estimate the fair value of our financial instruments.
We have entered into forward-starting interest rate swaps to hedge the interest rate risk on coupon payments of forecasted issuances
of long-term debt. These derivatives are designated as cash flow hedges. Credit risk is considered in the fair value calculation of
each agreement. As they are based on observable data and valuations of similar instruments, the hedges are categorized within
Level 2 of the fair value hierarchy. There was no exchange of premium at the initial date of the swaps and we can settle the contracts
at any time. For additional information, see Note 9, "Risk Management Activities."
NIPSCO has entered into long-term forward natural gas purchase instruments that range from five to ten years to lock in a fixed
price for its natural gas customers. We value these contracts using a pricing model that incorporates market-based information
when available, as these instruments trade less frequently and are classified within Level 2 of the fair value hierarchy. For additional
information see Note 9, “Risk Management Activities.”
107
Table of Contents
NISOURCE INC.
Notes to Consolidated Financial Statements
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (continued)
Available-for-sale securities are investments pledged as collateral for trust accounts related to our wholly-owned insurance
company. Available-for-sale securities are included within “Other investments” in the Consolidated Balance Sheets. We value
U.S. Treasury, corporate debt and mortgage-backed securities using a matrix pricing model that incorporates market-based
information. These securities trade less frequently and are classified within Level 2. Total unrealized gains and losses from available-
for-sale securities are included in other comprehensive income. The amortized cost, gross unrealized gains and losses and fair
value of available-for-sale securities at December 31, 2019 and 2018 were:
December 31, 2019 (in millions)
Available-for-sale securities
U.S. Treasury debt securities
Corporate/Other debt securities
Total
December 31, 2018 (in millions)
Available-for-sale securities
U.S. Treasury debt securities
Corporate/Other debt securities
Total
Amortized
Cost
Gross
Unrealized
Gains
Gross
Unrealized
Losses
Fair Value
$
$
$
$
31.4
118.7
150.1
Amortized
Cost
23.6
117.7
141.3
$
$
$
$
0.1
4.2
4.3
Gross
Unrealized
Gains
0.1
0.4
0.5
$
$
$
$
(0.1) $
(0.1)
(0.2) $
31.4
122.8
154.2
Gross
Unrealized
Losses
Fair Value
(0.1) $
(3.4)
(3.5) $
23.6
114.7
138.3
Realized gains and losses on available-for-sale securities were immaterial for the year-ended December 31, 2019 and 2018.
The cost of maturities sold is based upon specific identification. At December 31, 2019, approximately $7.7 million of U.S.
Treasury debt securities and approximately $6.0 million of Corporate/Other debt securities have maturities of less than a year.
There are no material items in the fair value reconciliation of Level 3 assets and liabilities measured at fair value on a recurring
basis for the years ended December 31, 2019 and 2018.
Non-recurring Fair Value Measurements. We measure the fair value of certain assets on a non-recurring basis, typically annually
or when events or changes in circumstances indicate that the carrying amount of the assets may not be recoverable. These assets
include goodwill and other intangible assets.
At December 31, 2019, we recorded an impairment charge of $204.8 million for goodwill and an impairment charge of $209.7
million for franchise rights, in each case related to Columbia of Massachusetts. For additional information, see Note 6, “Goodwill
and Other Intangible Assets.”
B. Other Fair Value Disclosures for Financial Instruments. The carrying amount of cash and cash equivalents, restricted
cash, notes receivable, customer deposits and short-term borrowings is a reasonable estimate of fair value due to their liquid or
short-term nature. Our long-term borrowings are recorded at historical amounts.
The following method and assumptions were used to estimate the fair value of each class of financial instruments.
Long-term debt. The fair value of outstanding long-term debt is estimated based on the quoted market prices for the same or
similar securities. Certain premium costs associated with the early settlement of long-term debt are not taken into consideration
in determining fair value. These fair value measurements are classified within Level 2 of the fair value hierarchy. For the years
ended December 31, 2019 and 2018, there was no change in the method or significant assumptions used to estimate the fair value
of long-term debt.
108
Table of Contents
NISOURCE INC.
Notes to Consolidated Financial Statements
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (continued)
The carrying amount and estimated fair values of these financial instruments were as follows:
At December 31, (in millions)
Long-term debt (including current portion)
18.
Transfers of Financial Assets
Carrying
Amount
2019
Estimated
Fair Value
2019
Carrying
Amount
2018
Estimated
Fair Value
2018
$
7,869.6
$
8,764.4
$
7,155.4
$
7,228.3
Columbia of Ohio, NIPSCO and Columbia of Pennsylvania each maintain a receivables agreement whereby they transfer their
customer accounts receivables to third party financial institutions through wholly-owned and consolidated special purpose entities.
The three agreements expire between May 2020 and October 2020 and may be further extended if mutually agreed to by the parties
thereto.
All receivables transferred to third parties are valued at face value, which approximates fair value due to their short-term nature.
The amount of the undivided percentage ownership interest in the accounts receivables transferred is determined in part by required
loss reserves under the agreements.
Transfers of accounts receivable are accounted for as secured borrowings resulting in the recognition of short-term borrowings
on the Consolidated Balance Sheets. As of December 31, 2019, the maximum amount of debt that could be recognized related to
our accounts receivable programs is $465.0 million.
The following table reflects the gross receivables balance and net receivables transferred as well as short-term borrowings related
to the securitization transactions as of December 31, 2019 and 2018:
At December 31, (in millions)
Gross receivables
Less: receivables not transferred
Net receivables transferred
Short-term debt due to asset securitization
2019
2018
$
$
$
569.1
215.9
353.2
353.2
$
$
$
694.4
295.2
399.2
399.2
During 2019, $46.0 million was recorded as cash flows used for financing activities related to the change in short-term borrowings
due to securitization transactions. During 2018, $62.5 million was recorded as cash flows from financing activities related to the
change in short-term borrowings due to securitization transactions. Fees associated with the securitization transactions were $2.6
million, $2.6 million and $2.5 million for the years ended December 31, 2019, 2018 and 2017, respectively. Columbia of Ohio,
NIPSCO and Columbia of Pennsylvania remain responsible for collecting on the receivables securitized, and the receivables
cannot be transferred to another party.
109
Table of Contents
NISOURCE INC.
Notes to Consolidated Financial Statements
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (continued)
19.
Other Commitments and Contingencies
A.
Contractual Obligations. We have certain contractual obligations requiring payments at specified periods. The
obligations include long-term debt, lease obligations, energy commodity contracts and obligations for various services including
pipeline capacity and outsourcing of IT services. The total contractual obligations in existence at December 31, 2019 and their
maturities were:
(in millions)
Long-term debt (1)
Interest payments on long-term debt
Finance leases(2)
Operating leases(3)
Energy commodity contracts(4)
Service obligations:
Pipeline service obligations
IT service obligations
Other service obligations(5)
Other liabilities
Total
2020
2021
2022
2023
2024
After
$
7,738.6
$
— $
63.6
$
530.0
$
600.0
$
— $
6,545.0
6,214.2
325.9
79.1
95.9
3,450.7
153.2
59.8
27.3
342.0
340.7
27.2
15.6
65.5
27.3
9.4
30.4
605.0
590.1
63.6
45.8
27.3
49.4
14.0
—
337.1
26.8
8.2
—
546.8
38.0
—
—
311.1
23.1
7.6
—
299.9
19.9
6.6
—
4,583.4
201.6
31.7
—
357.2
237.5
1,114.1
1.1
—
—
1.1
—
—
—
—
—
Total contractual obligations
$
$
1,192.0
18,144.7
1,124.9
(1) Long-term debt balance excludes unamortized issuance costs and discounts of $70.5 million.
(2) Finance lease payments shown above are inclusive of interest totaling $108.3 million.
(3) Operating lease payments shown above are inclusive of interest totaling $14.3 million. Operating lease balances do not include obligations for possible fleet
vehicle lease renewals beyond the initial lease term. While we have the ability to renew these leases beyond the initial term, we are not reasonably certain (as that
term is defined in ASC 842) to do so. If we were to continue the fleet vehicle leases outstanding at December 31, 2019, payments would be $34.5 million in 2020,
$28.3 million in 2021, $23.4 million in 2022, $19.9 million in 2023, $15.2 million in 2024 and $15.2 million thereafter.
(4)In January 2020, NIPSCO signed new coal contract commitments of $14.4 million for 2020. These contracts are not included above.
(5)In February 2020, NIPSCO signed a new railcar coal transportation contract commitment of $12.0 million for 2020. This contract is not included above.
12,475.8
1,486.9
1,300.1
565.0
$
$
$
$
$
Operating and Finance Lease Commitments. We lease assets in several areas of our operations including corporate and field
offices, railcars, fleet vehicles and certain IT assets. Payments made in connection with operating and month-to-month leases were
$52.5 million in 2019, $49.1 million in 2018 and $49.5 million in 2017, and are primarily charged to operation and maintenance
expense as incurred. See Note 16, "Leases" for additional details.
Purchase and Service Obligations. We have entered into various purchase and service agreements whereby we are contractually
obligated to make certain minimum payments in future periods. Our purchase obligations are for the purchase of physical quantities
of natural gas, electricity and coal. Our service agreements encompass a broad range of business support and maintenance functions
which are generally described below.
Our subsidiaries have entered into various energy commodity contracts to purchase physical quantities of natural gas, electricity
and coal. These amounts represent minimum quantities of these commodities we are obligated to purchase at both fixed and
variable prices. To the extent contractual purchase prices are variable, obligations disclosed in the table above are valued at market
prices as of December 31, 2019.
In July 2008, the IURC issued an order approving NIPSCO’s purchase power agreements with subsidiaries of Iberdrola Renewables,
Buffalo Ridge I LLC and Barton Windpower LLC. These agreements provide NIPSCO the opportunity and obligation to purchase
up to 100 MW of wind power generated commencing in early 2009. The contracts extend 15 and 20 years, representing 50 MW
of wind power each. No minimum quantities are specified within these agreements due to the variability of electricity generation
from wind, so no amounts related to these contracts are included in the table above. Upon any termination of the agreements by
NIPSCO for any reason (other than material breach by Buffalo Ridge I LLC or Barton Windpower LLC), NIPSCO may be required
to pay a termination charge that could be material depending on the events giving rise to termination and the timing of the
termination. NIPSCO began purchasing wind power in April 2009.
We have pipeline service agreements that provide for pipeline capacity, transportation and storage services. These agreements,
which have expiration dates ranging from 2020 to 2045, require us to pay fixed monthly charges.
110
Table of Contents
NISOURCE INC.
Notes to Consolidated Financial Statements
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (continued)
NIPSCO has contracts with three major rail operators providing for coal transportation services for which there are certain minimum
payments. These service contracts extend for various periods through 2021.
We have executed agreements with multiple IT service providers. The agreements extend for various periods through 2024.
B.
Guarantees and Indemnities. We and certain subsidiaries enter into various agreements providing financial or
performance assurance to third parties on behalf of certain subsidiaries as part of normal business. Such agreements include
guarantees and stand-by letters of credit. These agreements are entered into primarily to support or enhance the creditworthiness
otherwise attributed to a subsidiary on a stand-alone basis, thereby facilitating the extension of sufficient credit to accomplish the
subsidiaries’ intended commercial purposes. At December 31, 2019 and 2018, we had issued stand-by letters of credit of $10.2
million for the benefit of third parties.
C.
Legal Proceedings.
On September 13, 2018, a series of fires and explosions occurred in Lawrence, Andover and North Andover, Massachusetts related
to the delivery of natural gas by Columbia of Massachusetts (the "Greater Lawrence Incident"). The Greater Lawrence Incident
resulted in one fatality and a number of injuries, damaged multiple homes and businesses, and caused the temporary evacuation
of significant portions of each municipality. The Massachusetts Governor’s Office declared a state of emergency, authorizing the
Massachusetts DPU to order another utility company to coordinate the restoration of utility services in Lawrence, Andover and
North Andover. The incident resulted in the interruption of gas for approximately 7,500 gas meters, the majority of which served
residences and approximately 700 of which served businesses, and the interruption of other utility service more broadly in the
area. Columbia of Massachusetts has replaced the cast iron and bare steel gas pipeline system in the affected area and restored
service to nearly all of the gas meters. See “ - E. Other Matters - Greater Lawrence Pipeline Replacement” below for more
information.
We are subject to inquiries and investigations by government authorities and regulatory agencies regarding the Greater Lawrence
Incident, including the Massachusetts DPU and the Massachusetts Attorney General's Office, as described below. We are
cooperating with all inquiries and investigations. In addition, on February 26, 2020, the Company and Columbia of Massachusetts
entered into agreements with the U.S. Attorney’s Office to resolve the U.S. Attorney’s Office’s investigation relating to the Greater
Lawrence Incident, as described below.
NTSB Investigation. As previously disclosed, the NTSB concluded its investigation into the Greater Lawrence Incident, and we
are implementing the one remaining safety recommendation resulting from the investigation.
Massachusetts Investigations. Under Massachusetts law, the DPU is authorized to investigate potential violations of pipeline
safety regulations and to assess a civil penalty of up to $218,647 for a violation of federal pipeline safety regulations. A separate
violation occurs for each day of violation up to $2.2 million for a related series of violations. The Massachusetts DPU also is
authorized to investigate potential violations of the Columbia of Massachusetts emergency response plan and to assess penalties
of up to $250,000 per violation per day, or up to $20 million per related series of violations. Further, as a result of the declaration
of emergency by the Governor, the DPU is authorized to investigate potential violations of the DPU's operational directives during
the restoration efforts and assess penalties of up to $1 million per violation. Pursuant to these authorities, the DPU is investigating
Columbia of Massachusetts as described below. Columbia of Massachusetts will likely be subject to potential compliance actions
related to the Greater Lawrence Incident and the restoration work following the incident, the timing and outcomes of which are
uncertain at this time.
After the Greater Lawrence Incident, the Massachusetts DPU retained an independent evaluator to conduct a statewide examination
of the safety of the natural gas distribution system and the operational and maintenance functions of natural gas companies in the
Commonwealth of Massachusetts. Through authority granted by the Massachusetts Governor under the state of emergency, the
Chair of the Massachusetts DPU has directed all natural gas distribution companies operating in the Commonwealth to fund the
statewide examination. The statewide examination is complete. The Phase I report, which was issued in May 2019, included a
program level assessment and evaluation of natural gas distribution companies. The Phase I report's conclusions were statewide
and contained no specific conclusions about Columbia of Massachusetts. Phase II, which was focused on field assessments of
each Massachusetts gas company, concluded in December 2019. The Phase II report made several observations about and
recommendations to Massachusetts gas companies, including Columbia of Massachusetts, with regard to safety culture and assets.
The final report was issued in late January 2020, and the DPU directed each natural gas distribution company operating in
Massachusetts to submit a plan in response to the report no later than February 28, 2020.
111
Table of Contents
NISOURCE INC.
Notes to Consolidated Financial Statements
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (continued)
On September 11, 2019, the Massachusetts DPU issued an order directing Columbia of Massachusetts to take several specific
actions to address concerns related to service lines abandoned during the restoration work following the Greater Lawrence Incident
and to furnish certain information and periodic reports to the DPU.
On October 1, 2019, the Massachusetts DPU issued four orders to Columbia of Massachusetts in connection with the service lines
abandoned during the Greater Lawrence Incident restoration, which require: (1) the submission of a detailed work plan to the
DPU, (2) the completion of quality control work on certain abandoned services, (3) the payment for a third-party independent
audit, to be contracted through the DPU, of all gas pipeline work completed as part of the incident restoration effort, and (4) prompt
and full response to any requests for information by the third-party auditor. The Massachusetts DPU retained an independent
evaluator to conduct this audit, and that third party is currently evaluating compliance with Massachusetts and federal law, as well
as any other operational or safety risks that may be posed by the pipeline work. The audit scope also includes Columbia of
Massachusetts' operations in the Lawrence Division and other service territories as appropriate.
Also in October 2019, the Massachusetts DPU issued three additional orders requiring: (1) daily leak surveillance and reporting
in areas where abandoned services are located, (2) completion by November 15, 2019 of the work plan previously submitted
describing how Columbia of Massachusetts would address the estimated 2,200 locations at which an inside meter set was moved
outside the property as part of the abandoned service work completed during the Greater Lawrence Incident restoration, and (3)
submission of a report by December 2, 2019 showing any patterns, trends or correlations among the non-compliant work related
to the abandonment of service lines, gate boxes and curb boxes during the incident restoration.
On October 3, 2019, the Massachusetts DPU notified Columbia of Massachusetts that, absent DPU approval, it is currently allowed
to perform only emergency work on its gas distribution system throughout its service territories in Massachusetts. The restrictions
do not apply to Columbia of Massachusetts’ work to address the previously identified issues with abandoned service lines and
valve boxes in the Greater Lawrence, Massachusetts area. Columbia of Massachusetts is subject to daily monitoring by the DPU
on any work that Columbia of Massachusetts conducts in Massachusetts. Such restrictions on work remain in place until modified
by the DPU.
On October 25, 2019, the Massachusetts DPU issued two orders opening public investigations into Columbia of Massachusetts
with respect to the Greater Lawrence Incident. The Massachusetts DPU opened the first investigation under its authority to determine
compliance with federal and state pipeline safety laws and regulations, and to investigate Columbia of Massachusetts’ responsibility
for and response to the Greater Lawrence Incident and its restoration efforts following the incident. The Massachusetts DPU
opened the second investigation under its authority to determine whether a gas distribution company has violated established
standards regarding acceptable performance for emergency preparedness and restoration of service to investigate efforts by
Columbia of Massachusetts to prepare for and restore service following the Greater Lawrence Incident. Separate penalties are
applicable under each exercise of authority.
On December 23, 2019, the Massachusetts DPU issued an order defining the scope of its investigation into the response of Columbia
of Massachusetts related to the Greater Lawrence Incident. The DPU identified three distinct time frames in which Columbia of
Massachusetts handled emergency response and restoration directly: (1) September 13-14, 2018, (2) September 21 through
December 16, 2018 (the Phase I restoration), and (3) September 27, 2019 through completion of restoration of outages resulting
from the gas release event in Lawrence, Massachusetts that occurred on September 27, 2019. The DPU determined that it is
appropriate to investigate separately, for each time period described above, the areas of response, recovery and restoration for
which Columbia of Massachusetts was responsible. The DPU noted that it also may investigate the continued restoration and
related repair work that took place after December 16, 2018 and, depending on the outcome of that investigation, may deem it
appropriate to consider that period of restoration as an additional separate time period.
The DPU also noted that its investigation into all of the above described time periods is ongoing and that if the DPU determines,
based on its investigation, that it is appropriate to treat the separate time frames as separate emergency events, it may impose up
to the maximum statutory penalty for each event, pursuant to Mass. G.L. c. 164 Section 1J. This provision authorizes the DPU to
investigate potential violations of the Columbia of Massachusetts emergency response plan and to assess penalties of up to $250,000
per violation per day, or up to $20 million per related series of violations. The DPU noted that at this preliminary stage of the
investigation, it does not have the factual basis to make those determinations.
In connection with its investigation related to the Greater Lawrence Incident, on February 4, 2020, the Massachusetts Attorney
General's Office issued a request for documents primarily focused on the restoration work following the incident.
112
Table of Contents
NISOURCE INC.
Notes to Consolidated Financial Statements
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (continued)
Columbia of Massachusetts is cooperating with the investigations set forth above as well as other inquiries resulting from an
increased amount of enforcement activity, for all of which the outcomes are uncertain at this time.
Massachusetts Legislative Matters. On November 12, 2019, the Joint Committee on Telecommunications, Utilities and Energy
held a hearing that focused on gas safety, but the Committee has not taken action on any bills. Increased scrutiny related to gas
system safety and regulatory oversight in Massachusetts, including additional legislative oversight hearings and new legislative
proposals, is expected to continue during the current two-year legislative session that ends in December 2020.
U.S. Department of Justice Investigation. As previously disclosed, the Company and Columbia of Massachusetts are subject to
a criminal investigation related to the Greater Lawrence Incident that is being conducted under the supervision of the U.S. Attorney's
Office. The initial grand jury subpoenas were served on the Company and Columbia of Massachusetts on September 24, 2018.
On February 26, 2020, the Company and Columbia of Massachusetts entered into agreements with the U.S. Attorney’s Office to
resolve the U.S. Attorney’s Office’s investigation relating to the Greater Lawrence Incident. Columbia of Massachusetts agreed
to plead guilty in the United States District Court for the District of Massachusetts (the “Court”) to violating the Natural Gas
Pipeline Safety Act (the “Plea Agreement”), and the Company entered into a DPA.
Under the Plea Agreement, which must be approved by the Court, Columbia of Massachusetts will be subject to the following
terms, among others: (i) a criminal fine in the amount of $53,030,116 paid within 30 days of sentencing; (ii) a three year probationary
period that will early terminate upon a sale of Columbia of Massachusetts or a sale of its gas distribution business to a qualified
third-party buyer consistent with certain requirements; (iii) compliance with each of the NTSB recommendations stemming from
the Greater Lawrence Incident; and (iv) employment of an in-house monitor during the term of the probationary period.
Under the DPA, the U.S. Attorney’s Office agreed to defer prosecution of the Company in connection with the Greater Lawrence
Incident for a three-year period (which three-year period may be extended for twelve (12) months upon the U.S. Attorney’s Office’s
determination of a breach of the DPA) subject to certain obligations of the Company, including, but not limited to, the following:
(i) the Company will use reasonable best efforts to sell Columbia of Massachusetts or Columbia of Massachusetts’ gas distribution
business to a qualified third-party buyer consistent with certain requirements, and, upon the completion of any such sale, the
Company will cease and desist any and all gas pipeline and distribution activities in the District of Massachusetts; (ii) the Company
will forfeit and pay, within 30 days of the later of the sale becoming final or the date on which post-closing adjustments to the
purchase price are finally determined in accordance with the agreement to sell Columbia Gas of Massachusetts or its gas distribution
business, a fine equal to the total amount of any profit or gain from any sale of Columbia of Massachusetts or its gas distribution
business, with the amount of profit or gain determined as provided in the DPA; and (iii) the Company agrees as to each of the
Company’s subsidiaries involved in the distribution of gas through pipeline facilities in Massachusetts, Indiana, Ohio, Pennsylvania,
Maryland, Kentucky and Virginia to implement and adhere to each of the recommendations from the NTSB stemming from the
Greater Lawrence Incident. Pursuant to the DPA, if the Company complies with all of its obligations under the DPA, including,
but not limited to those identified above, the U.S. Attorney’s Office will not file any criminal charges against the Company related
to the Greater Lawrence Incident. If Columbia of Massachusetts’ guilty plea is not accepted by the Court or is withdrawn for any
reason, or if Columbia of Massachusetts should fail to perform an obligation under the Plea Agreement prior to the sale of Columbia
of Massachusetts or its gas distribution business, the U.S. Attorney's Office may, at its sole option, render the DPA null and void.
U.S. Congressional Activity. On September 30, 2019, the U.S. Pipeline Safety Act expired. There is no effect on PHMSA's authority.
Action on past re-authorization bills has extended past the expiration date and action on this re-authorization is expected to continue
well into 2020. Pipeline safety jurisdiction resides with the U.S. Senate Commerce Committee, and is divided between two
committees in the U.S. House of Representatives (Energy and Commerce, and Transportation and Infrastructure). Legislative
proposals are currently in various stages of committee development and the timing of further action is uncertain. Certain legislative
proposals, if enacted into law, may increase costs for natural gas industry companies, including the Company and Columbia of
Massachusetts.
SEC Investigation. On November 27, 2019, the SEC staff notified the Company that it concluded its investigation related to
disclosures made by the Company prior to the Greater Lawrence Incident and, based on the information provided as of such date,
it does not intend to recommend an enforcement action against the Company.
Private Actions. Various lawsuits, including several purported class action lawsuits, have been filed by various affected residents
or businesses in Massachusetts state courts against the Company and/or Columbia of Massachusetts in connection with the Greater
Lawrence Incident. A special judge has been appointed to hear all pending and future cases and the class actions have been
consolidated into one class action. On January 14, 2019, the special judge granted the parties’ joint motion to stay all cases until
113
Table of Contents
NISOURCE INC.
Notes to Consolidated Financial Statements
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (continued)
April 30, 2019 to allow mediation, and the parties subsequently agreed to extend the stay until July 25, 2019. The class action
lawsuits allege varying causes of action, including those for strict liability for ultra-hazardous activity, negligence, private nuisance,
public nuisance, premises liability, trespass, breach of warranty, breach of contract, failure to warn, unjust enrichment, consumer
protection act claims, negligent, reckless and intentional infliction of emotional distress and gross negligence, and seek actual
compensatory damages, plus treble damages, and punitive damages.
On July 26, 2019, the Company, Columbia of Massachusetts and NiSource Corporate Services Company, a subsidiary of the
Company, entered into a term sheet with the class action plaintiffs under which they agreed to settle the class action claims in
connection with the Greater Lawrence Incident. Columbia of Massachusetts agreed to pay $143 million into a settlement fund to
compensate the settlement class and the settlement class agreed to release Columbia of Massachusetts and affiliates from all claims
arising out of or related to the Greater Lawrence Incident. The following claims are not covered under the proposed settlement
because they are not part of the consolidated class action: (1) physical bodily injury and wrongful death; (2) insurance subrogation,
whether equitable, contractual or otherwise; and (3) claims arising out of appliances that are subject to the Massachusetts DPU
orders. Emotional distress and similar claims are covered under the proposed settlement unless they are secondary to a physical
bodily injury. The settlement class is defined under the term sheet as all persons and businesses in the three municipalities of
Lawrence, Andover and North Andover, Massachusetts, subject to certain limited exceptions. The motion for preliminary approval
and the settlement documents were filed on September 25, 2019. The preliminary approval court hearing was held on October 7,
2019 and the court issued an order granting preliminary approval of the settlement on October 11, 2019. The proposed settlement
is subject to final court approval, and a hearing occurred on February 27, 2020. The court took the matter under advisement.
Many residents and business owners have submitted individual damage claims to Columbia of Massachusetts. Most of the wrongful
death and bodily injury claims that have been asserted have been settled, and we continue to discuss potential settlements with
plaintiffs asserting such claims. In addition, the Commonwealth of Massachusetts is seeking reimbursement from Columbia of
Massachusetts for its expenses incurred in connection with the Greater Lawrence Incident. The outcomes and impacts of such
private actions are uncertain at this time.
Financial Impact. Since the Greater Lawrence Incident, we have recorded expenses of approximately $1,041 million for third-
party claims and fines, penalties and settlements associated with government investigations. We estimate that total costs related
to third-party claims and fines, penalties and settlements associated with government investigations resulting from the incident
will range from $1,041 million to $1,065 million, depending on the number, nature, final outcome and value of third-party claims
and the final outcome of government investigations. With regard to third-party claims, these costs include, but are not limited to,
personal injury and property damage claims, damage to infrastructure, business interruption claims, and mutual aid payments to
other utilities assisting with the restoration effort. These costs do not include costs of certain third-party claims and fines, penalties
or settlements associated with government investigations that we are not able to estimate, nor do they include non-claims related
and government investigation-related legal expenses resulting from the incident and the capital cost of the pipeline replacement,
which are set forth in " - E. Other Matters - Greater Lawrence Incident Restoration" and "- Greater Lawrence Incident Pipeline
Replacement," respectively, below.
The process for estimating costs associated with third-party claims and fines, penalties, and settlements associated with government
investigations relating to the Greater Lawrence Incident requires management to exercise significant judgment based on a number
of assumptions and subjective factors. As more information becomes known, including additional information regarding ongoing
investigations, management’s estimates and assumptions regarding the financial impact of the Greater Lawrence Incident may
change.
The aggregate amount of third-party liability insurance coverage available for losses arising from the Greater Lawrence Incident
is $800 million. We have collected the entire $800 million as of December 31, 2019. Total expenses related to the incident have
exceeded the total amount of insurance coverage available under our policies. Refer to "- E. Other Matters - Greater Lawrence
Incident Restoration," below for a summary of third-party claims-related expense activity and associated insurance recoveries
recorded since the Greater Lawrence Incident.
We are also party to certain other claims, regulatory and legal proceedings arising in the ordinary course of business in each state
in which we have operations, none of which is deemed to be individually material at this time.
Due to the inherent uncertainty of litigation, there can be no assurance that the resolution of any particular claim, proceeding or
investigation related to the Greater Lawrence Incident or otherwise would not have a material adverse effect on our results of
operations, financial position or liquidity. Certain matters in connection with the Greater Lawrence Incident have had or may have
a material impact as described above. If one or more of such additional or other matters were decided against us, the effects could
114
Table of Contents
NISOURCE INC.
Notes to Consolidated Financial Statements
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (continued)
be material to our results of operations in the period in which we would be required to record or adjust the related liability and
could also be material to our cash flows in the periods that we would be required to pay such liability.
Environmental Matters. Our operations are subject to environmental statutes and regulations related to air quality, water
D.
quality, hazardous waste and solid waste. We believe that we are in substantial compliance with the environmental regulations
currently applicable to our operations.
It is management's continued intent to address environmental issues in cooperation with regulatory authorities in such a manner
as to achieve mutually acceptable compliance plans. However, there can be no assurance that fines and penalties will not be
incurred. Management expects a significant portion of environmental assessment, improvement and remediation costs to be
recoverable through rates for certain of our companies.
As of December 31, 2019 and 2018, we had recorded a liability of $104.4 million and $101.2 million, respectively, to cover
environmental remediation at various sites. The current portion of this liability is included in "Legal and environmental" in the
Consolidated Balance Sheets. The noncurrent portion is included in "Other noncurrent liabilities." We recognize costs associated
with environmental remediation obligations when the incurrence of such costs is probable and the amounts can be reasonably
estimated. The original estimates for remediation activities may differ materially from the amount ultimately expended. The actual
future expenditures depend on many factors, including currently enacted laws and regulations, the nature and extent of impact
and the method of remediation. These expenditures are not currently estimable at some sites. We periodically adjust our liability
as information is collected and estimates become more refined.
Electric Operations' compliance estimates disclosed below are reflective of NIPSCO's Integrated Resource Plan submitted to the
IURC on October 31, 2018. See section " - E. Other Matters - NIPSCO 2018 Integrated Resource Plan," below for additional
information.
Air
Future legislative and regulatory programs could significantly limit allowed GHG emissions or impose a cost or tax on GHG
emissions. Additionally, rules that require further GHG reductions or impose additional requirements for natural gas facilities
could impose additional costs. NiSource will carefully monitor all GHG reduction proposals and regulations.
ACE Rule. On July 8, 2019, the EPA published the final ACE rule, which establishes emission guidelines for states to use when
developing plans to limit carbon dioxide at coal-fired electric generating units based on heat rate improvement measures. The
coal-fired units at NIPSCO’s R.M. Schahfer Generating Station and Michigan City Generating Station are potentially affected
sources, and compliance requirements for these units which NIPSCO plans to retire by 2023 and 2028, respectively, will be
determined by future Indiana rulemaking. The ACE rule notes that states have “broad flexibility in setting standards of performance
for designated facilities” and that a state may set a “business as usual” standard for sources that have a remaining useful life “so
short that imposing any costs on the electric generating unit is unreasonable.” State plans are due by 2022, and the EPA will have
six months to determine completeness and then one additional year to determine whether to approve the submitted plan. States
have the discretion to determine the compliance period for each source. As a result, NIPSCO will continue to monitor this matter
and cannot estimate its impact at this time.
Waste
CERCLA. Our subsidiaries are potentially responsible parties at waste disposal sites under the CERCLA (commonly known as
Superfund) and similar state laws. Under CERCLA, each potentially responsible party can be held jointly, severally and strictly
liable for the remediation costs as the EPA, or state, can allow the parties to pay for remedial action or perform remedial action
themselves and request reimbursement from the potentially responsible parties. Our affiliates have retained CERCLA
environmental liabilities, including remediation liabilities, associated with certain current and former operations. These liabilities
are not material to the Consolidated Financial Statements.
MGP. A program has been instituted to identify and investigate former MGP sites where Gas Distribution Operations subsidiaries
or predecessors may have liability. The program has identified 63 such sites where liability is probable. Remedial actions at many
of these sites are being overseen by state or federal environmental agencies through consent agreements or voluntary remediation
agreements.
We utilize a probabilistic model to estimate our future remediation costs related to MGP sites. The model was prepared with the
assistance of a third party and incorporates our experience and general industry experience with remediating MGP sites. We
complete an annual refresh of the model in the second quarter of each fiscal year. No material changes to the estimated future
remediation costs were noted as a result of the refresh completed as of June 30, 2019. Our total estimated liability related to the
115
Table of Contents
NISOURCE INC.
Notes to Consolidated Financial Statements
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (continued)
facilities subject to remediation was $102.2 million and $97.5 million at December 31, 2019 and 2018, respectively. The liability
represents our best estimate of the probable cost to remediate the facilities. We believe that it is reasonably possible that remediation
costs could vary by as much as $20 million in addition to the costs noted above. Remediation costs are estimated based on the
best available information, applicable remediation standards at the balance sheet date, and experience with similar facilities.
CCRs. On April 17, 2015, the EPA issued a final rule for regulation of CCRs. The rule regulates CCRs under the RCRA Subtitle
D, which determines them to be nonhazardous. The rule is implemented in phases and requires increased groundwater monitoring,
reporting, recordkeeping and posting of related information to the Internet. The rule also establishes requirements related to CCR
management and disposal. The rule will allow NIPSCO to continue its byproduct beneficial use program.
To comply with the rule, NIPSCO completed capital expenditures to modify its infrastructure and manage CCRs during 2019.
The CCR rule also resulted in revisions to previously recorded legal obligations associated with the retirement of certain NIPSCO
facilities. The actual asset retirement costs related to the CCR rule may vary substantially from the estimates used to record the
increased asset retirement obligation due to the uncertainty about the requirements that will be established by environmental
authorities, compliance strategies that will be used and the preliminary nature of available data used to estimate costs. As allowed
by the rule, NIPSCO will continue to collect data over time to determine the specific compliance solutions and associated costs
and, as a result, the actual costs may vary. NIPSCO has filed initial CCR closure plans for R.M. Schahfer Generating Station and
Michigan City Generating Station with the Indiana Department of Environmental Management.
Water
ELG. On November 3, 2015, the EPA issued a final rule to amend the ELG and standards for the Steam Electric Power Generating
category. Based upon a study performed in 2016 of the final rule, capital compliance costs were expected to be approximately $170.0
million. The EPA has proposed revisions to the final rule, and public comments were due on January 21, 2020. NIPSCO does not
anticipate material ELG compliance costs based on the preferred option announced as part of NIPSCO's 2018 Integrated Resource
Plan (discussed below).
E. Other Matters.
NIPSCO 2018 Integrated Resource Plan. Multiple factors, but primarily economic ones, including low natural gas prices,
advancing cost effective renewable technology and increasing capital and operating costs associated with existing coal plants,
have led NIPSCO to conclude in its October 2018 Integrated Resource Plan submission that NIPSCO’s current fleet of coal
generation facilities will be retired earlier than previous Integrated Resource Plans had indicated.
The Integrated Resource Plan evaluated demand-side and supply-side resource alternatives to reliably and cost effectively meet
NIPSCO customers' future energy requirements over the ensuing 20 years. The preferred option within the Integrated Resource
Plan retires R.M. Schahfer Generating Station (Units 14, 15, 17, and 18) by 2023 and Michigan City Generating Station (Unit 12)
by 2028. These units represent 2,080 MW of generating capacity, equal to 72% of NIPSCO’s remaining generating capacity (and
100% of NIPSCO's remaining coal-fired generating capacity) after the retirement of Bailly Units 7 and 8 on May 31, 2018.
The current replacement plan includes renewable sources of energy, including wind, solar, and battery storage to be obtained
through a combination of NIPSCO ownership and PPAs.
In January 2019, NIPSCO executed two 20 year PPAs to purchase 100% of the output from renewable generation facilities at a
fixed price per MWh. NIPSCO submitted the PPAs to the IURC for approval in February 2019 and the IURC approved the PPAs
on June 5, 2019. Payments under the PPAs will not begin until the associated generation facilities are constructed by the owner /
seller which is currently scheduled to be complete by the end of 2020 for one facility. NIPSCO has filed a notice with the IURC
of its intention not to move forward with one of its approved PPAs due to the failure to meet a condition precedent in the agreement
as a result of local zoning restrictions.
Also in January 2019, NIPSCO executed a BTA with a developer to construct a renewable generation facility with a nameplate
capacity of approximately 100 MW. Once complete, ownership of the facility would be transferred to a joint venture owned by
NIPSCO, the developer and an unrelated tax equity partner. The aforementioned joint venture is expected to be fully owned by
NIPSCO after the PTC are monetized from the project (approximately 10 years after the facility goes into service). NIPSCO's
purchase requirement under the BTA is dependent on satisfactory approval of the BTA by the IURC, successful execution of an
agreement with a tax equity partner, and timely completion of construction. NIPSCO submitted the BTA to the IURC for approval
in February 2019 and the IURC approved the BTA on August 7, 2019. Required FERC filings occurred after receiving the IURC
order and the related approvals were received. Construction of the facility is expected to be completed by the end of 2020.
116
Table of Contents
NISOURCE INC.
Notes to Consolidated Financial Statements
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (continued)
On October 1, 2019, NIPSCO announced the opening of its next round of RFP to consider potential resources to meet the future
electric needs of its customers. The RFP closed on November 20, 2019, and NIPSCO continues to evaluate the results. NIPSCO
is considering all sources in the RFP process.
In October 2019, NIPSCO executed a BTA with a developer to construct an additional renewable generation facility with a
nameplate capacity of approximately 300 MW. Once complete, ownership of the facility would be transferred to a joint venture
owned by NIPSCO, the developer and an unrelated tax equity partner. The aforementioned joint venture is expected to be fully
owned by NIPSCO after the PTC are monetized from the project (approximately 10 years after the facility goes into service).
NIPSCO's purchase requirement under the BTA is dependent on satisfactory approval of the BTA by the IURC, successful execution
of an agreement with a tax equity partner, and timely completion of construction. NIPSCO submitted the BTA to the IURC for
approval on October 22, 2019, and the IURC approved the BTA on February 19, 2020. Required FERC filings are expected to be
filed by the end of June 2020. Construction of the facility is expected to be completed by the end of 2021.
Greater Lawrence Incident Restoration. In addition to the amounts estimated for third-party claims and fines, penalties and
settlements associated with government investigations described above, since the Greater Lawrence Incident, we have recorded
expenses of approximately $420 million for other incident-related costs. We estimate that total other incident-related costs will
range from $450 million to $460 million, depending on the incurrence of costs associated with resolving outstanding inquiries
and investigations discuss above in " - C. Legal Proceedings." Such costs include certain consulting costs, legal costs, vendor
costs, claims center costs, labor and related expenses incurred in connection with the incident, and insurance-related loss surcharges.
The amounts set forth above do not include the capital cost of the pipeline replacement, which is set forth below, or any estimates
for fines and penalties, which are discussed above in " - C. Legal Proceedings."
As discussed in "- C. Legal Proceedings," the aggregate amount of third-party liability insurance coverage available for losses
arising from the Greater Lawrence Incident is $800 million. We have collected the entire $800 million as of December 31, 2019.
Expenses related to the incident have exceeded the total amount of insurance coverage available under our policies.
The following table summarizes expenses incurred and insurance recoveries recorded since the Greater Lawrence Incident. This
activity is presented within "Operation and maintenance" and "Other, net" in our Statements of Consolidated Income (Loss).
(in millions)
Third-party claims and government fines, penalties and settlements
Other incident-related costs
Total
Insurance recoveries recorded
Loss (benefit) to income before income taxes
Year Ended
Year Ended
December 31,
2018
December 31,
2019
Incident to
Date
$
$
757
266
1,023
(135)
888
$
$
284 $
154
438
(665)
(227) $
1,041
420
1,461
(800)
661
117
Table of Contents
NISOURCE INC.
Notes to Consolidated Financial Statements
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (continued)
The following table presents activity related to our Greater Lawrence Incident insurance recovery, which we have recovered in
full as of December 31, 2019.
(in millions)
Balance, December 31, 2018
Insurance recoveries recorded in first quarter of 2019
Cash collected from insurance recoveries in the first quarter of 2019
Balance, March 31, 2019
Insurance recoveries recorded in the second quarter of 2019
Cash collected from insurance recoveries in the second quarter of 2019
Balance, June 30, 2019
Insurance recoveries recorded in third quarter of 2019
Cash collected from insurance recoveries in the third quarter of 2019
Balance, September 30, 2019
Insurance recoveries recorded in the fourth quarter of 2019
Cash collected from insurance recoveries in the fourth quarter of 2019
Balance, December 31, 2019
(1)$5 million of insurance recoveries were collected during 2018.
Insurance
receivable(1)
130
$
100
(108)
122
435
(297)
260
—
(260)
—
130
(130)
—
$
$
$
Greater Lawrence Pipeline Replacement. In connection with the Greater Lawrence Incident, Columbia of Massachusetts, in
cooperation with the Massachusetts Governor’s office, replaced the entire affected 45-mile cast iron and bare steel pipeline system
that delivers gas to approximately 7,500 gas meters, the majority of which serve residences and approximately 700 of which serve
businesses impacted in the Greater Lawrence Incident. This system was replaced with plastic distribution mains and service lines,
as well as enhanced safety features such as pressure regulation and excess flow valves at each premise.
Since the Greater Lawrence Incident and through December 31, 2019, we have invested approximately $258 million of capital
spend for the pipeline replacement; this work was completed in 2019. We maintain property insurance for gas pipelines and other
applicable property. Columbia of Massachusetts has filed a proof of loss with its property insurer for the full cost of the pipeline
replacement. In January 2020, we filed a lawsuit against the property insurer, seeking payment of our property claim. We are
currently unable to predict the timing or amount of any insurance recovery under the property policy. The recovery of any capital
investment not reimbursed through insurance will be addressed in a future regulatory proceeding; a future regulatory proceeding
is dependent on the outcome of the sale of the Massachusetts Business. The outcome of such a proceeding (if any) is uncertain.
In accordance with ASC 980-360, if it becomes probable that a portion of the pipeline replacement cost will not be recoverable
through customer rates and an amount can be reasonably estimated, we will reduce our regulated plant balance for the amount of
the probable disallowance and record an associated charge to earnings. This could result in a material adverse effect to our financial
condition, results of operations and cash flows. Additionally, if a rate order is received allowing recovery of the investment with
no or reduced return on investment, a loss on disallowance may be required.
State Income Taxes Related to Greater Lawrence Incident Expenses. As of December 31, 2018, expenses related to the Greater
Lawrence Incident were $1,023 million. In the fourth quarter of 2019, we filed an application for Alternative Apportionment with
the MA DOR to request an allocable approach to these expenses for purposes of Massachusetts state income taxes, which, if
approved, would result in a state deferred tax asset of approximately $50 million, net. The MA DOR is expected to review the
application within nine months from the date of filing, and we believe it is reasonably possible that the application will be accepted,
or an alternative method proposed.
118
Table of Contents
NISOURCE INC.
Notes to Consolidated Financial Statements
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (continued)
20.
Accumulated Other Comprehensive Loss
The following table displays the activity of Accumulated Other Comprehensive Loss, net of tax:
(in millions)
Balance as of January 1, 2017
Other comprehensive income (loss) before reclassifications
Amounts reclassified from accumulated other comprehensive loss
Net current-period other comprehensive income (loss)
Balance as of December 31, 2017
Other comprehensive income (loss) before reclassifications
Amounts reclassified from accumulated other comprehensive loss
Net current-period other comprehensive income (loss)
Reclassification due to adoption of ASU 2018-02
Balance as of December 31, 2018
Other comprehensive income (loss) before reclassifications
Amounts reclassified from accumulated other comprehensive loss
Net current-period other comprehensive income (loss)
Balance as of December 31, 2019
(1)All amounts are net of tax. Amounts in parentheses indicate debits.
$
$
$
$
21.
Other, Net
Year Ended December 31, (in millions)
Interest income
Gains and
Losses on
Securities(1)
Gains and Losses
on Cash Flow
Hedges(1)
Pension and
OPEB Items(1)
Accumulated
Other
Comprehensive
Loss(1)
(0.6) $
(6.9) $
(17.6) $
0.6
0.2
0.8
0.2
(3.0)
0.4
(2.6)
—
(24.2)
1.7
(22.5)
1.9
1.5
3.4
$
(29.4) $
(14.2) $
55.8
(33.1)
22.7
(6.3)
(4.4)
—
(4.4)
(3.2)
(2.4) $
(13.0) $
(21.8) $
(64.3)
0.1
(64.2)
2.3
0.8
3.1
(77.2) $
(18.7) $
(25.1)
(21.7)
3.4
(18.3)
(43.4)
48.4
(32.7)
15.7
(9.5)
(37.2)
(55.9)
0.5
(55.4)
(92.6)
6.1
(0.4)
5.7
3.3
$
$
2019
2018
2017
7.7
$
6.6
$
4.6
AFUDC equity
Charitable contributions(1)
Interest rate swap settlement gain(3)
Pension and other postretirement non-service cost(2)
12.6
(19.9)
(10.6)
—
Miscellaneous
(0.2)
Total Other, net
(13.5)
(1) 2018 charitable contributions include $20.7 million related to the Greater Lawrence Incident and $20.0 million of discretionary contributions made to the
Nisource Charitable Foundation. See Note 19, "Other Commitments and Contingencies" for additional information on the Greater Lawrence Incident.
(2) See Note 11, "Pension and Other Postretirement Benefits" for additional information.
(3) See Note 9, "Risk Management Activities" for additional information.
8.0
(5.1)
(16.5)
—
14.2
(45.3)
18.0
0.7
(5.2) $
46.2
43.5
3.8
$
$
119
Table of Contents
NISOURCE INC.
Notes to Consolidated Financial Statements
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (continued)
22.
Interest Expense, Net
Year Ended December 31, (in millions)
Interest on long-term debt
Interest on short-term borrowings
Debt discount/cost amortization
Accounts receivable securitization fees
Allowance for borrowed funds used and interest capitalized during
construction
Debt-based post-in-service carrying charges
Other
Total Interest Expense, net
23.
Segments of Business
2019
2018
2017
$
327.7
$
342.2
$
50.8
8.3
2.6
(7.5)
(18.7)
15.7
31.8
7.7
2.6
(9.1)
(35.0)
13.1
$
378.9
$
353.3
$
354.8
14.9
7.2
2.5
(6.2)
(36.4)
16.4
353.2
At December 31, 2019, our operations are divided into two primary reportable segments. The Gas Distribution Operations segment
provides natural gas service and transportation for residential, commercial and industrial customers in Ohio, Pennsylvania, Virginia,
Kentucky, Maryland, Indiana and Massachusetts. The Electric Operations segment provides electric service in 20 counties in the
northern part of Indiana.
The following table provides information about our reportable segments. We use operating income as our primary measurement
for each of the reported segments and make decisions on finance, dividends and taxes at the corporate level on a consolidated
basis. Segment revenues include intersegment sales to affiliated subsidiaries, which are eliminated in consolidation. Affiliated
sales are recognized on the basis of prevailing market, regulated prices or at levels provided for under contractual agreements.
Operating income is derived from revenues and expenses directly associated with each segment.
Year Ended December 31, (in millions)
Operating Revenues
Gas Distribution Operations
Unaffiliated
Intersegment
Total
Electric Operations
Unaffiliated
Intersegment
Total
Corporate and Other
Unaffiliated
Intersegment
Total
Eliminations
Consolidated Operating Revenues
2019
2018
2017
$
$
$
3,509.7
13.1
3,522.8
1,698.4
0.8
1,699.2
0.8
468.1
468.9
(482.0)
5,208.9
$
$
3,406.4
13.1
3,419.5
1,707.4
0.8
1,708.2
0.7
517.6
518.3
(531.5)
5,114.5
$
3,087.9
14.2
3,102.1
1,785.7
0.8
1,786.5
1.0
510.8
511.8
(525.8)
4,874.6
120
Table of Contents
NISOURCE INC.
Notes to Consolidated Financial Statements
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (continued)
Year Ended December 31, (in millions)
Operating Income (Loss)
Gas Distribution Operations
Electric Operations
Corporate and Other(2)
Consolidated Operating Income
Depreciation and Amortization
Gas Distribution Operations
Electric Operations
Corporate and Other
Consolidated Depreciation and Amortization
Assets
Gas Distribution Operations
Electric Operations
Corporate and Other
Consolidated Assets
Capital Expenditures(1)
Gas Distribution Operations
Electric Operations
Corporate and Other
$
$
$
$
$
$
$
2019
2018
2017
$
$
$
$
$
$
$
675.4
406.8
(191.5)
890.7
403.2
277.3
36.9
717.4
14,224.5
6,027.6
2,407.7
22,659.8
1,380.3
468.9
18.6
1,867.8
(254.1) $
386.1
(7.3)
124.7
$
$
$
$
$
$
301.0
262.9
35.7
599.6
13,527.0
5,735.2
2,541.8
21,804.0
1,315.3
499.3
—
1,814.6
550.1
367.4
3.7
921.2
269.3
277.8
23.2
570.3
12,048.8
5,478.6
2,434.3
19,961.7
1,125.6
592.4
35.8
1,753.8
Consolidated Capital Expenditures
(1)Amounts differ from those presented on the Statements of Consolidated Cash Flows primarily due to the inclusion of capital expenditures included in current
liabilities and AFUDC Equity.
(2) In 2019, Corporate and Other reflects an impairment charge of $204.8 million for goodwill related to Columbia of Massachusetts. For additional information,
see Note 6, "Goodwill and Other Intangible Assets."
$
$
$
121
Table of Contents
NISOURCE INC.
Notes to Consolidated Financial Statements
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (continued)
24.
Quarterly Financial Data (Unaudited)
Quarterly financial data does not always reveal the trend of our business operations due to nonrecurring items and seasonal weather
patterns, which affect earnings and related components of revenue and operating income.
(in millions, except per share data)
2019
Operating Revenues
Operating Income (Loss)
Net Income (Loss)
Preferred Dividends
Net Income (Loss) Available to Common Shareholders
Earnings (Loss) Per Share
Basic Earnings (Loss) Per Share
Diluted Earnings (Loss) Per Share
2018
Operating Revenues
Operating Income (Loss)
Net Income (Loss)
Preferred Dividends
Net Income (Loss) Available to Common Shareholders
Earnings (Loss) Per Share
$
$
$
$
First
Quarter(1)
Second
Quarter(2)
Third
Quarter(3)
Fourth
Quarter(4)
$
$
$
$
1,869.8
374.2
218.9
(13.8)
205.1
0.55
0.55
1,750.8
400.6
276.1
—
276.1
$
$
$
$
1,010.4
463.5
296.9
(13.8)
283.1
0.76
0.75
1,007.0
118.4
24.5
(1.3)
23.2
$
931.5
91.0
6.6
(13.8)
(7.2)
(0.02) $
(0.02) $
$
895.0
(315.9)
(339.5)
(5.6)
(345.1)
1,397.2
(38.0)
(139.3)
(13.7)
(153.0)
(0.41)
(0.41)
1,461.7
(78.4)
(11.7)
(8.1)
(19.8)
$
$
Basic Earnings (Loss) Per Share
Diluted Earnings (Loss) Per Share
(0.05)
(0.05)
(1) Net income for the first quarter of 2019 was impacted by $108.0 million in insurance recoveries (pretax) related to the Greater Lawrence Incident. See Note 19-
E, "Other Matters" for additional information.
(2) Net income for the second quarter of 2019 was impacted by $297.0 million in insurance recoveries (pretax) related to the Greater Lawrence Incident. See Note
19-E, "Other Matters" for additional information.
(3) Net loss for the third quarter of 2018 was impacted by approximately $462 million in expenses (pretax) related to the Greater Lawrence Incident restoration and
a $33.0 million loss (pretax) on an early extinguishment of long-term debt. See Note 19-E, "Other Matters" and Note 14, "Long-Term Debt" for additional
information.
(4) Net loss for the fourth quarter of 2019 was impacted by an impairment charge of $204.8 million for goodwill and an impairment charge of $209.7 million for
franchise rights, in each case related to Columbia of Massachusetts. For additional information, see Note 6, "Goodwill and Other Intangible Assets."
(0.95) $
(0.95) $
0.82
0.81
0.07
0.07
$
$
$
$
25.
Supplemental Cash Flow Information
The following table provides additional information regarding our Consolidated Statements of Cash Flows for the years ended
December 31, 2019, 2018 and 2017:
Year Ended December 31, (in millions)
Supplemental Disclosures of Cash Flow Information
Non-cash transactions:
Capital expenditures included in current liabilities
Assets acquired under a finance lease
Assets acquired under an operating lease
Reclassification of other property to regulatory assets(1)
Assets recorded for asset retirement obligations(2)
Schedule of interest and income taxes paid:
Cash paid for interest, net of interest capitalized amounts
Cash paid for income taxes, net of refunds
(1)See Note 8 "Regulatory Matters" for additional information.
(2)See Note 7 "Asset Retirement Obligations" for additional information.
122
2019
2018
2017
$
$
$
223.6
26.4
13.4
—
54.6
$
152.0
54.6
—
245.3
78.1
$
349.7
10.8
$
354.2
3.3
173.0
11.5
—
—
11.4
339.9
5.5
Table of Contents
NISOURCE INC.
Notes to Consolidated Financial Statements
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (continued)
26.
Subsequent Event
On February 26, 2020, NiSource and Columbia of Massachusetts entered into the Asset Purchase Agreement with Eversource.
Upon the terms and subject to the conditions set forth in the Asset Purchase Agreement, NiSource and Columbia of Massachusetts
agreed to sell to Eversource, with certain additions and exceptions: (1) substantially all of the assets of Columbia of Massachusetts
and (2) all of the assets held by any of Columbia of Massachusetts’ affiliates that primarily relate to the Massachusetts Business,
and Eversource agreed to assume certain liabilities of Columbia of Massachusetts and its affiliates. The liabilities assumed by
Eversource under the Asset Purchase Agreement do not include, among others, any liabilities arising out of the Greater Lawrence
Incident or liabilities of Columbia of Massachusetts or its affiliates pursuant to civil claims for injury of persons or damage to
property to the extent such injury or damage occurs prior to the closing in connection with the Massachusetts Business. The Asset
Purchase Agreement provides for a purchase price of $1,100 million in cash, subject to adjustment based on Columbia of
Massachusetts’ net working capital as of the closing. The closing of the transactions contemplated by the Asset Purchase Agreement
is subject to Hart-Scott Rodino Antitrust Improvements Act of 1976 and regulatory approvals, resolution of certain proceedings
before governmental bodies and other conditions. The Massachusetts Business did not meet the requirements under GAAP to be
classified as held-for-sale as of December 31, 2019. When the Massachusetts Business meets the requirements to be classified as
held-for-sale, in each period leading up to the closing date of the transaction, the assets and liabilities of the Massachusetts Business
will be measured at fair value, less costs to sell. The final pre-tax gain or loss on the transaction will be determined as of the closing
date. Assuming the Massachusetts Business is classified as held-for-sale at March 31, 2020, we estimate that the total pre-tax loss
to be measured in the quarter ended March 31, 2020 will be approximately $360 million, based on December 31, 2019 asset and
liability balances and estimated transaction costs. This estimated pre-tax loss is subject to change based on estimated transaction
costs, working capital adjustments and asset and liability balances at each measurement date leading up to the closing date. The
sale is expected to close by September 30, 2020, subject to closing conditions.
123
Table of Contents
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA (continued)
NISOURCE INC.
SCHEDULE II – VALUATION AND QUALIFYING ACCOUNTS
Twelve months ended December 31, 2019
Additions
($ in millions)
Reserves Deducted in Consolidated Balance Sheet from Assets to
Which They Apply:
Balance
Jan. 1, 2019
Charged to
Costs and
Expenses
Charged to
Other
Account (1)
Deductions for
Purposes for
which Reserves
were Created
Balance
Dec. 31, 2019
Reserve for accounts receivable
Reserve for other investments
$
21.1
$
21.6
$
41.3
$
64.8
$
3.0
—
—
—
19.2
3.0
Twelve months ended December 31, 2018
Additions
($ in millions)
Reserves Deducted in Consolidated Balance Sheet from Assets to
Which They Apply:
Balance
Jan. 1, 2018
Charged to
Costs and
Expenses
Charged to
Other
Account (1)
Deductions for
Purposes for
which Reserves
were Created
Balance
Dec. 31, 2018
Reserve for accounts receivable
Reserve for other investments
$
18.3
$
20.2
$
43.7
$
61.1
$
3.0
—
—
—
21.1
3.0
Twelve months ended December 31, 2017
Additions
($ in millions)
Reserves Deducted in Consolidated Balance Sheet from Assets to
Which They Apply:
Balance
Jan. 1, 2017
Charged to
Costs and
Expenses
Charged to
Other
Account (1)
Deductions for
Purposes for
which Reserves
were Created
Balance
Dec. 31, 2017
Reserve for accounts receivable
Reserve for other investments
$
23.3
$
14.8
$
39.1
$
58.9
$
3.0
—
—
—
18.3
3.0
(1) Charged to Other Accounts reflects the deferral of bad debt expense to a regulatory asset.
124
Table of Contents
NISOURCE INC.
ITEM 9. CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING AND FINANCIAL
DISCLOSURE
None.
ITEM 9A. CONTROLS AND PROCEDURES
Evaluation of Disclosure Controls and Procedures
Our chief executive officer and chief financial officer are responsible for evaluating the effectiveness of disclosure controls and
procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)). Our disclosure controls and procedures are designed to
provide reasonable assurance that the information required to be disclosed by the Company in reports that are filed or submitted
under the Exchange Act are accumulated and communicated to management, including our chief executive officer and chief
financial officer, as appropriate, to allow timely decisions regarding required disclosure and is recorded, processed, summarized
and reported within the time periods specified in the rules and forms of the SEC. Based upon that evaluation, our chief executive
officer and chief financial officer concluded that, as of the end of the period covered by this report, disclosure controls and procedures
were effective to provide reasonable assurance that financial information was processed, recorded and reported accurately.
Management’s Annual Report on Internal Control over Financial Reporting
Our management, including our chief executive officer and chief financial officer, are responsible for establishing and maintaining
internal control over financial reporting, as such term is defined under Rule 13a-15(f) or Rule 15d-15(f) promulgated under the
Exchange Act. However, management would note that a control system can provide only reasonable, not absolute, assurance that
the objectives of the control system are met. Our management has adopted the 2013 framework set forth in the Committee of
Sponsoring Organizations of the Treadway Commission report, Internal Control - Integrated Framework, the most commonly used
and understood framework for evaluating internal control over financial reporting, as its framework for evaluating the reliability
and effectiveness of internal control over financial reporting. During 2019, we conducted an evaluation of our internal control
over financial reporting. Based on this evaluation, management concluded that our internal control over financial reporting was
effective as of the end of the period covered by this annual report.
Deloitte & Touche LLP, our independent registered public accounting firm, issued an attestation report on our internal controls
over financial reporting which is included herein.
Changes in Internal Controls
There have been no changes in our internal control over financial reporting during the most recently completed quarter covered
by this report that has materially affected, or is reasonably likely to materially affect, our internal control over financial reporting.
125
Table of Contents
ITEM 9A. CONTROLS AND PROCEDURES
NISOURCE INC.
REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM
To the stockholders and the Board of Directors of NiSource Inc.
Opinion on Internal Control over Financial Reporting
We have audited the internal control over financial reporting of NiSource Inc. and subsidiaries (the “Company”) as of December
31, 2019, 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 Company maintained, in all material respects, effective
internal control over financial reporting as of December 31, 2019, based on criteria established in Internal Control - Integrated
Framework (2013) issued by COSO.
We have also audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States)
(PCAOB), the consolidated financial statements as of and for the year ended December 31, 2019, of the Company and our report
dated February 27, 2020, expressed an unqualified opinion on those financial statements.
Basis for Opinion
The Company’s management is responsible for maintaining effective internal control over financial reporting and for its assessment
of the effectiveness of internal control over financial reporting, included in the accompanying Management's Report on Internal
Control Over Financial Reporting. Our responsibility is to express an opinion on the Company’s internal control over financial
reporting based on our audit. We are a public accounting firm registered with the 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 audit in accordance with the standards of the PCAOB. Those standards require that we plan and perform the
audit to obtain reasonable assurance about whether effective internal control over financial reporting was maintained in all material
respects. Our audit included obtaining an understanding of internal control over financial reporting, assessing the risk that a material
weakness exists, testing and evaluating the design and operating effectiveness of internal control based on the assessed risk, and
performing such other procedures as we considered necessary in the circumstances. We believe that our audit provides a reasonable
basis for our opinion.
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 (1) pertain
to the maintenance of records that, in reasonable detail, accurately and fairly reflect the transactions and dispositions of the assets
of the company; (2) 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 (3) 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.
/s/ DELOITTE & TOUCHE LLP
Columbus, Ohio
February 27, 2020
126
Table of Contents
ITEM 9B. OTHER INFORMATION
NISOURCE INC.
Not applicable.
127
Table of Contents
NISOURCE INC.
PART III
ITEM 10. DIRECTORS, EXECUTIVE OFFICERS AND CORPORATE GOVERNANCE
Except for the information required by this item with respect to our executive officers included at the end of Part I of this report
on Form 10-K, the information required by this Item 10 is incorporated herein by reference to the discussion in "Proposal 1 Election
of Directors," and "Corporate Governance" of the Proxy Statement for the Annual Meeting of Stockholders to be held on May 19,
2020.
ITEM 11. EXECUTIVE COMPENSATION
The information required by this Item 11 is incorporated herein by reference to the discussion in "Corporate Governance -
Compensation Committee Interlocks and Insider Participation," "Director Compensation," "Executive Compensation," and
"Executive Compensation - Compensation Committee Report," of the Proxy Statement for the Annual Meeting of Stockholders
to be held on May 19, 2020.
ITEM 12. SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND MANAGEMENT AND RELATED
STOCKHOLDER MATTERS
The information required by this Item 12 is incorporated herein by reference to the discussion in "Security Ownership of Certain
Beneficial Owners and Management" and "Equity Compensation Plan Information" of the Proxy Statement for the Annual Meeting
of Stockholders to be held on May 19, 2020.
ITEM 13. CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS, AND DIRECTOR INDEPENDENCE
The information required by this Item 13 is incorporated herein by reference to the discussion in "Corporate Governance - Policies
and Procedures with Respect to Transactions with Related Persons" and "Corporate Governance - Director Independence" of the
Proxy Statement for the Annual Meeting of Stockholders to be held on May 19, 2020.
ITEM 14. PRINCIPAL ACCOUNTING FEES AND SERVICES
The information required by this Item 14 is incorporated herein by reference to the discussion in "Independent Auditor Fees" of
the Proxy Statement for the Annual Meeting of Stockholders to be held on May 19, 2020.
128
Table of Contents
NISOURCE INC.
PART IV
ITEM 15. EXHIBITS, FINANCIAL STATEMENT SCHEDULES
Financial Statements and Financial Statement Schedules
The following financial statements and financial statement schedules filed as a part of the Annual Report on Form 10-K are included
in Item 8, "Financial Statements and Supplementary Data."
Report of Independent Registered Public Accounting Firm
Statements of Consolidated Income (Loss)
Statements of Consolidated Comprehensive Income (Loss)
Consolidated Balance Sheets
Statements of Consolidated Cash Flows
Statements of Consolidated Stockholders’ Equity
Notes to Consolidated Financial Statements
Schedule II
Page
51
54
55
56
58
59
61
124
Exhibits
The exhibits filed herewith as a part of this report on Form 10-K are listed on the Exhibit Index below. Each management contract
or compensatory plan or arrangement of ours, listed on the Exhibit Index, is separately identified by an asterisk.
Pursuant to Item 601(b), paragraph (4)(iii)(A) of Regulation S-K, certain instruments representing long-term debt of our subsidiaries
have not been included as Exhibits because such debt does not exceed 10% of the total assets of ours and our subsidiaries on a
consolidated basis. We agree to furnish a copy of any such instrument to the SEC upon request.
EXHIBIT
NUMBER DESCRIPTION OF ITEM
(1.1)
(1.2)
(2.1)
(2.2)
(3.1)
(3.2)
(3.3)
(3.4)
(3.5)
(3.6)
Form of Equity Distribution Agreement (incorporated by reference to Exhibit 1.1 to the NiSource Inc. Form 8-K
filed on November 1, 2018).
Form of Master Forward Sale Confirmation (incorporated by reference to Exhibit 1.2 to the NiSource Inc. Form
8-K filed on November 1, 2018).
Separation and Distribution Agreement, dated as of June 30, 2015, by and between NiSource Inc. and Columbia
Pipeline Group, Inc. (incorporated by reference to Exhibit 2.1 to the NiSource Inc. Form 8-K filed on July 2,
2015).
Asset Purchase Agreement, dated as of February 26, 2020, by and among NiSource Inc., Bay State Gas
Company d/b/a Columbia Gas of Massachusetts and Eversource Energy (incorporated by reference to Exhibit
2.1 of the NiSource Inc. Form 8-K filed on February 27, 2020).***
Amended and Restated Certificate of Incorporation (incorporated by reference to Exhibit 3.1 to the Registrant’s
Form 10-Q, filed with the Commission on August 3, 2015).
Certificate of Amendment of Amended and Restated Certificate of Incorporation of NiSource dated May 7, 2019
(incorporated by reference to Exhibit 3.1 of the NiSource Inc. Form 8-K filed on May 8, 2019).
Bylaws of NiSource Inc., as amended and restated through January 26, 2018 (incorporated by reference to
Exhibit 3.1 to the NiSource Inc. Form 8-K filed on January 26, 2018).
Certificate of Designations of 5.65% Series A Fixed-Rate Reset Cumulative Redeemable Perpetual Preferred
Stock (incorporated by reference to Exhibit 3.1 of the NiSource Inc. Form 8-K filed on June 12, 2018).
Form of Certificate of Designations of 6.50% Series B Fixed-Rate Reset Cumulative Redeemable Perpetual
Preferred Stock (incorporated by reference to Exhibit 3.1 of the NiSource Inc. Form 8-K filed on November 29,
2018).
Certificate of Designations of 6.50% Series B Fixed-Rate Reset Cumulative Redeemable Perpetual Preferred
Stock (incorporated by reference to Exhibit 3.1 of the NiSource Inc. Form 8-K filed on December 6, 2018).
129
Table of Contents
(3.7)
(4.1)
(4.2)
(4.3)
(4.4)
(4.5)
(4.6)
(4.7)
(4.8)
(4.9)
(4.10)
(4.11)
(4.12)
(4.13)
(4.14)
(4.15)
(4.16)
(4.17)
(4.18)
Certificate of Designations of Series B-1 Preferred Stock (incorporated by reference to Exhibit 3.1 to the
NiSource Inc. Form 8-K filed on December 27, 2018).
Indenture, dated as of March 1, 1988, by and between Northern Indiana Public Service Company ("NIPSCO")
and Manufacturers Hanover Trust Company, as Trustee (incorporated by reference to Exhibit 4 to the NIPSCO
Registration Statement (Registration No. 33-44193)).
First Supplemental Indenture, dated as of December 1, 1991, by and between Northern Indiana Public Service
Company and Manufacturers Hanover Trust Company, as Trustee (incorporated by reference to Exhibit 4.1 to
the NIPSCO Registration Statement (Registration No. 33-63870)).
Indenture Agreement, dated as of February 14, 1997, by and between NIPSCO Industries, Inc., NIPSCO Capital
Markets, Inc. and Chase Manhattan Bank as trustee (incorporated by reference to Exhibit 4.1 to the NIPSCO
Industries, Inc. Registration Statement (Registration No. 333-22347)).
Second Supplemental Indenture, dated as of November 1, 2000, by and among NiSource Capital Markets, Inc.,
NiSource Inc., New NiSource Inc., and The Chase Manhattan Bank, as trustee (incorporated by reference to
Exhibit 4.45 to the NiSource Inc. Form 10-K for the period ended December 31, 2000).
Indenture, dated November 14, 2000, among NiSource Finance Corp., NiSource Inc., as guarantor, and The
Chase Manhattan Bank, as Trustee (incorporated by reference to Exhibit 4.1 to the NiSource Inc. Form S-3,
dated November 17, 2000 (Registration No. 333-49330)).
Form of 3.490% Notes due 2027 (incorporated by reference to Exhibit 4.1 to the NiSource Inc. Form 8-K filed
on May 17, 2017).
Form of 4.375% Notes due 2047 (incorporated by reference to Exhibit 4.2 to the NiSource Inc. Form 8-K filed
on May 17, 2017).
Form of 3.950% Notes due 2048 (incorporated by reference to Exhibit 4.1 to the NiSource Inc. Form 8-K filed
on September 8, 2017).
Form of 2.650% Notes due 2022 (incorporated by reference to Exhibit 4.1 to the NiSource Inc. Form 8-K filed
on November 14, 2017).
Second Supplemental Indenture, dated as of November 30, 2017, between NiSource Inc. and The Bank of New
York Mellon, as trustee (incorporated by reference to Exhibit 4.4 to Post-Effective Amendment No. 1 to
Form S-3 filed November 30, 2017 (Registration No. 333-214360)).
Third Supplemental Indenture, dated as of November 30, 2017, between NiSource Inc. and The Bank of New
York Mellon, as trustee (incorporated by reference to Exhibit 4.2 to the NiSource Inc. Form 8-K filed on
December 1, 2017).
Second Supplemental Indenture, dated as of February 12, 2018, between Northern Indiana Public Service
Company and The Bank of New York Mellon, solely as successor trustee under the Indenture dated as of March
1, 1988 between the Company and Manufacturers Hanover Trust Company, as original trustee. (incorporated by
reference to Exhibit 4.1 to the NiSource Inc. Form 10-Q filed on May 2, 2018).
Third Supplemental Indenture, dated as of June 11, 2018, by and between NiSource Inc. and The Bank of New
York Mellon, as trustee (including form of 3.650% Notes due 2023) (incorporated by reference to Exhibit 4.1 of
the NiSource Inc. Form 8-K filed on June 12, 2018).
Deposit Agreement, dated as of December 5, 2018, among NiSource, Inc., Computershare Inc. and
Computershare Trust Company, N.A., acting jointly as depositary, and the holders from time to time of the
depositary receipts described therein (incorporated by reference to Exhibit 4.1 of the NiSource Inc. Form 8-
K filed on December 6, 2018).
Form of Depositary Receipt (incorporated by reference to Exhibit 4.1 of the NiSource Inc. Form 8-K filed on
December 6, 2018).
Amended and Restated Deposit Agreement, dated as of December 27, 2018, among NiSource, Inc.,
Computershare Inc. and Computershare Trust Company, N.A., acting jointly as depositary, and the holders from
time to time of the depositary receipts described therein (incorporated by reference to Exhibit 4.1 to the
NiSource Inc. Form 8-K filed on December 27, 2018).
Form of Depositary Receipt (incorporated by reference to Exhibit 4.1 to the NiSource Inc. Form 8-K filed on
December 27, 2018).
Form of 2.950% Notes due 2029 (incorporated by reference to Exhibit 4.1 to NiSource Inc. Form 8-K filed on
August 12, 2019).
130
Table of Contents
(4.19)
(4.20)
(10.1)
(10.2)
(10.3)
(10.4)
(10.5)
(10.6)
(10.7)
(10.8)
(10.9)
(10.10)
(10.11)
(10.12)
(10.13)
(10.14)
(10.15)
(10.16)
(10.17)
(10.18)
(10.19)
Amended and Restated NiSource Inc. Employee Stock Purchase Plan (incorporated by reference to Exhibit C to
the Registrant’s Definitive Proxy Statement on Schedule 14A, filed with the Commission on April 1, 2019).
Description of NiSource Inc.’s Securities Registered Under Section 12 of the Exchange Act. **
2010 Omnibus Incentive Plan (incorporated by reference to Exhibit B to the NiSource Inc. Definitive Proxy
Statement to Stockholders for the Annual Meeting held on May 11, 2010, filed on April 2, 2010).*
First Amendment to the 2010 Omnibus Incentive Plan (incorporated by reference to Exhibit 10.2 to the
NiSource Inc. Form 10-K filed on February 18, 2014.)*
2010 Omnibus Incentive Plan (incorporated by reference to Exhibit C to the NiSource Inc. Definitive Proxy
Statement to Stockholders for the Annual Meeting held on May 12, 2015, filed on April 7, 2015).*
Second Amendment to the NiSource Inc. 2010 Omnibus Incentive Plan (incorporated by reference to Exhibit
10.1 to the NiSource Inc. Form 8-K filed October 23, 2015.)*
Form of Amended and Restated 2013 Performance Share Agreement effective on implementation of the spin-off
on July 1, 2015, (under the 2010 Omnibus Incentive Plan)(incorporated by reference to Exhibit 10.1 to the
NiSource Inc. Form 10-Q filed on November 3, 2015).*
Form of Amended and Restated 2014 Performance Share Agreement effective on the implementation of the
spin-off on July 1, 2015, (under the 2010 Omnibus Incentive Plan)(incorporated by reference to Exhibit 10.2 to
the NiSource Inc. Form 10-Q filed on November 3, 2015).*
Form of Amendment to Restricted Stock Unit Award Agreement related to Vested but Unpaid NiSource
Restricted Stock Unit Awards for Nonemployee Directors of NiSource entered into as of July 13, 2015
(incorporated by reference to Exhibit 10.3 to the NiSource Inc. Form 10-Q filed on November 3, 2015).*
NiSource Inc. Nonemployee Director Retirement Plan, as amended and restated effective May 13, 2008
(incorporated by reference to Exhibit 10.2 to the NiSource Inc. Form 10-K filed on February 27, 2009).*
Supplemental Life Insurance Plan effective January 1, 1991, as amended, (incorporated by reference to Exhibit 2
to the NIPSCO Industries, Inc. Form 8-K filed on March 25, 1992).*
Revised Form of Change in Control and Termination Agreement (incorporated by reference to Exhibit 10.2 to
the NiSource Inc. Form 8-K filed on October 23, 2015.)*
Form of Restricted Stock Agreement under the 2010 Omnibus Incentive Plan (incorporated by reference to
Exhibit 10.18 to the NiSource Inc. Form 10-K filed on February 28, 2011).*
Form of Restricted Stock Unit Award Agreement for Non-employee directors under the Non-employee Director
Stock Incentive Plan (incorporated by reference to Exhibit 10.19 to the NiSource Inc. Form 10-K filed on
February 28, 2011).*
Form of Restricted Stock Unit Award Agreement for Nonemployee Directors under the 2010 Omnibus Incentive
Plan (incorporated by reference to Exhibit 10.1 to NiSource Inc. Form 10-Q filed on August 2, 2011).*
Form of Restricted Stock Unit Award Agreement under the 2010 Omnibus Incentive Plan.* (incorporated by
reference to Exhibit 10.17 to the NiSource Inc. Form 10-K filed on February 22, 2017)
Form of Restricted Stock Unit Award Agreement for Nonemployee Directors under the 2010 Omnibus Incentive
Plan. (incorporated by reference to Exhibit 10.18 to the NiSource Inc. Form 10-K filed on February 22, 2017) *
Amended and Restated NiSource Inc. Executive Deferred Compensation Plan effective November 1, 2012
(incorporated by reference to Exhibit 10.21 to the NiSource Inc. Form 10-K filed on February 19, 2013).*
NiSource Inc. Executive Severance Policy, as amended and restated, effective January 1, 2015 (incorporated by
reference to Exhibit 10.21 to the NiSource Inc. Form 10-K filed on February 18, 2015).*
Note Purchase Agreement, dated as of August 23, 2005, by and among NiSource Finance Corp., as issuer,
NiSource Inc., as guarantor, and the purchasers named therein (incorporated by reference to Exhibit 10.1 to the
NiSource Inc. Current Report on Form 8-K filed on August 26, 2005).
Amendment No. 1, dated as of November 10, 2008, to the Note Purchase Agreement by and among NiSource
Finance Corp., as issuer, NiSource Inc., as guarantor, and the purchasers whose names appear on the signature
page thereto (incorporated by reference to Exhibit 10.30 to the NiSource Inc. Form 10-K filed on February 27,
2009).
131
Table of Contents
(10.20)
(10.21)
(10.22)
(10.23)
(10.24)
(10.25)
(10.26)
(10.27)
(10.28)
(10.29)
(10.30)
(10.31)
(10.32)
(10.33)
(10.34)
(10.35)
(10.36)
Letter Agreement, dated as of March 17, 2015, by and between NiSource Inc. and Donald Brown. (incorporated
by reference Exhibit 10.1 to the NiSource Inc. Form 10-Q filed on April 30, 2015).*
Letter Agreement, dated as of February 23, 2016, by and between NiSource Inc. and Pablo A. Vegas.
(incorporated by reference Exhibit 10.29 to the NiSource Inc. Form 10-K filed on February 22, 2017).*
Employee Matters Agreement, dated as of June 30, 2015, by and between NiSource Inc. and Columbia Pipeline
Group, Inc. (incorporated by reference to Exhibit 10.2 of the NiSource Inc. Form 8-K filed on July 2, 2015).
Form of Change in Control and Termination Agreement (incorporated by reference to Exhibit 10.1 to the
NiSource Inc. Form 10-Q filed on August 2, 2017).
Form of Performance Share Award Agreement under the 2010 Omnibus Incentive Plan (incorporated by
reference to Exhibit 10.33 to the NiSource Form 10-K filed on February 20, 2018).*
Form of Restricted Stock Unit Award Agreement under the 2010 Omnibus Incentive Plan (incorporated by
reference to Exhibit 10.34 to the NiSource Form 10-K filed on February 20, 2018).*
Common Stock Subscription Agreement, dated as of May 2, 2018, by and among NiSource Inc. and the
purchasers named therein (incorporated by reference to Exhibit 10.1 of the NiSource Inc. Form 8-K filed on
May 2, 2018).
Registration Rights Agreement, dated as of May 2, 2018, by and among NiSource Inc. and the purchasers named
therein (incorporated by reference to Exhibit 10.2 of the NiSource Inc. Form 8-K filed on May 2, 2018).
Purchase Agreement, dated as of June 6, 2018, by and among NiSource Inc. and Credit Suisse Securities (USA)
LLC, J.P. Morgan Securities LLC, Morgan Stanley & Co. LLC and MUFG Securities Americas Inc., as
representatives, relating to the 5.650% Series A Preferred Stock (incorporated by reference to Exhibit 10.1 of the
NiSource Inc. Form 8-K filed on June 12, 2018).
Purchase Agreement, dated as of June 6, 2018, by and among NiSource Inc. and Credit Suisse Securities (USA)
LLC, J.P. Morgan Securities LLC, Morgan Stanley & Co. LLC and MUFG Securities Americas Inc., as
representatives, relating to the 3.650% Notes due 2023 (incorporated by reference to Exhibit 10.2 of the
NiSource Inc. Form 8-K filed on June 12, 2018).
Registration Rights Agreement, dated as of June 11, 2018, by and among NiSource Inc. and Credit Suisse
Securities (USA) LLC, J.P. Morgan Securities LLC, Morgan Stanley & Co. LLC and MUFG Securities
Americas Inc., as representatives, relating to the 5.650% Series A Preferred Stock (incorporated by reference to
Exhibit 10.3 of the NiSource Inc. Form 8-K filed on June 12, 2018).
Registration Rights Agreement, dated as of June 11, 2018, by and among NiSource Inc. and Credit Suisse
Securities (USA) LLC, J.P. Morgan Securities LLC, Morgan Stanley & Co. LLC and MUFG Securities
Americas Inc., as representatives, relating to the 3.650% Notes due 2023 (incorporated by reference to Exhibit
10.4 of the NiSource Inc. Form 8-K filed on June 12, 2018).
Amended and Restated NiSource Inc. Supplemental Executive Retirement Plan effective August 10, 2017
(incorporated by reference to Exhibit 10.1 of the NiSource Inc. Form 10-Q filed on November 1, 2018).
Amended and Restated Pension Restoration Plan for NiSource Inc. and Affiliates effective August 10, 2017
(incorporated by reference to Exhibit 10.2 of the NiSource Inc. Form 10-Q filed on November 1, 2018).
Amended Restated Savings Restoration Plan for NiSource Inc. and Affiliates effective August 10, 2017
(incorporated by reference to Exhibit 10.3 of the NiSource Inc. Form 10-Q filed on November 1, 2018).
Form of 2019 Performance Share Award Agreement under the 2010 Omnibus Incentive Plan. (incorporated by
reference to Exhibit 10.45 of the NiSource Inc. Form 10-K filed on February 20, 2019).
Fifth Amended and Restated Revolving Credit Agreement, dated as of February 20, 2019, among NiSource Inc.,
as Borrower, the Lenders party thereto, Barclays Bank PLC, as Administrative Agent, Citibank, N.A. and
MUFG Bank, Ltd., as Co-Syndication Agents, Credit Suisse AG, Cayman Islands Branch, JPMorgan Chase
Bank, N.A. and Wells Fargo Bank, National Association, as Co-Documentation Agents, and Barclays Bank PLC,
Citibank, N.A., MUFG Bank, Ltd., Credit Suisse Loan Funding LLC, JPMorgan Chase Bank, N.A. and Wells
Fargo Securities, LLC, as Joint Lead Arrangers and Joint Bookrunners (incorporated by reference to Exhibit
10.1 of the NiSource Inc. Form 8-K filed on February 20, 2019).
(10.37)
Amended and Restated NiSource Inc. Employee Stock Purchase Plan adopted as of February 1, 2019
(incorporated by reference to Exhibit C to the NiSource Inc. Definitive Proxy Statement to Stockholders for the
Annual Meeting to be held on May 7, 2019, filed on April 1, 2019).
132
Table of Contents
(10.38)
Amended and Restated Term Loan Agreement, dated as of April 17, 2019, among NiSource Inc., as Borrower,
the Lenders party thereto, and MUFG Bank Ltd., as Administrative Agent and Sole Lead Arranger and Sole
Bookrunner (incorporated by reference to Exhibit 10.1 of the NiSource Inc. Form 8-K filed on April 17, 2019).
(10.39)
Form of Performance Share Award Agreement* **
(10.40)
Form of Restricted Stock Unit Award Agreement* **
(10.41)
Form of Cash-Based Award Agreement* **
(10.42)
(10.43)
(21)
(23)
(31.1)
(31.2)
(32.1)
(32.2)
Columbia Gas of Massachusetts Plea Agreement dated February 26, 2020 (incorporated by reference to Exhibit
10.2 of the NiSource Inc. Form 8-K filed on February 27, 2020).
NiSource Deferred Prosecution Agreement dated February 26, 2020 (incorporated by reference to Exhibit 10.1
of the NiSource Inc. Form 8-K filed on February 27, 2020).
List of Subsidiaries.**
Consent of Deloitte & Touche LLP.**
Certification of Chief Executive Officer, pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.**
Certification of Chief Financial Officer, pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.**
Certification of Chief Executive Officer, pursuant to Section 906 of the Sarbanes-Oxley Act of 2002 (furnished
herewith).**
Certification of Chief Financial Officer, pursuant to Section 906 of the Sarbanes-Oxley Act of 2002 (furnished
herewith).**
(101.INS)
Inline XBRL Instance Document - the instance document does not appear in the Interactive Data File because its
XBRL tags are embedded within the Inline XBRL document. **
(101.SCH)
Inline XBRL Schema Document.**
(101.CAL)
Inline XBRL Calculation Linkbase Document.**
(101.LAB)
Inline XBRL Labels Linkbase Document.**
(101.PRE)
Inline XBRL Presentation Linkbase Document.**
(101.DEF)
Inline XBRL Definition Linkbase Document.**
(104)
Cover page Interactive Data File (formatted as inline XBRL, and contained in Exhibit 101.)
*
**
***
Management contract or compensatory plan or arrangement of NiSource Inc.
Exhibit filed herewith.
Schedules and exhibits have been omitted pursuant to Item 601(b)(2) of Regulation S-K. NiSource agrees to furnish
supplementally a copy of any omitted schedules or exhibits to the SEC upon request.
References made to NIPSCO filings can be found at Commission File Number 001-04125. References made to NiSource Inc.
filings made prior to November 1, 2000 can be found at Commission File Number 001-09779.
133
Table of Contents
SIGNATURES
Pursuant to the requirements of Section 13 or 15(d) of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf
by the undersigned, hereunto duly authorized.
(Registrant)
NiSource Inc.
Date: February 27, 2020
By:
/s/ JOSEPH HAMROCK
Joseph Hamrock
President, Chief Executive Officer and Director
(Principal Executive Officer)
Pursuant to the requirements of the Securities Exchange Act of 1934, this report has been signed below by the following persons on behalf of the registrant and
in the capacities and on the dates indicated.
/s/
JOSEPH HAMROCK
Joseph Hamrock
/s/ DONALD E. BROWN
Donald E. Brown
/s/
JOSEPH W. MULPAS
Joseph W. Mulpas
/s/ KEVIN T. KABAT
Kevin T. Kabat
/s/
PETER A. ALTABEF
Peter A. Altabef
President, Chief
Executive Officer and Director
(Principal Executive Officer)
Executive Vice President and
Chief Financial Officer
(Principal Financial Officer)
Vice President and
Chief Accounting Officer
(Principal Accounting Officer)
Date: February 27, 2020
Date: February 27, 2020
Date: February 27, 2020
Chairman and Director
Date: February 27, 2020
Director
Date: February 27, 2020
/s/
THEODORE H. BUNTING, JR.
Director
Date: February 27, 2020
Theodore H. Bunting, Jr.
/s/
ERIC L. BUTLER
Eric L. Butler
/s/ ARISTIDES S. CANDRIS
Aristides S. Candris
/s/ WAYNE S. DEVEYDT
Wayne S. DeVeydt
/s/ DEBORAH A. HENRETTA
Deborah A. Henretta
/s/ DEBORAH A.P. HERSMAN
Deborah A. P. Hersman
/s/ MICHAEL E. JESANIS
Michael E. Jesanis
/s/ CAROLYN Y. WOO
Carolyn Y. Woo
Director
Director
Director
Director
Director
Director
Director
134
Date: February 27, 2020
Date: February 27, 2020
Date: February 27, 2020
Date: February 27, 2020
Date: February 27, 2020
Date: February 27, 2020
Date: February 27, 2020
STOCKHOLDER INFORMATION
Forward-Looking Statements
This document contains “forward-looking statements” within the meaning of federal securities laws. Investors and prospective investors should understand that
many factors govern whether any forward-looking statement contained herein will be or can be realized. Any one of those factors could cause actual results to
differ materially from those projected. Examples of forward-looking statements in this press release include, but are not limited to, statements and expectations
regarding NiSource’s or any of its subsidiaries’ plans, strategies, objectives, expected performance, expenditures, recovery of expenditures through rates, stated
on either a consolidated or segment basis, and any and all underlying assumptions and other statements that are other than statements of historical fact. All
forward-looking statements are based on assumptions that management believes to be reasonable; however, there can be no assurance that actual results will
not differ materially. Factors that could cause actual results to differ materially from the projections, forecasts, estimates, and expectations discussed in this press
release include, among other things, NiSource’s debt obligations; any changes in NiSource’s credit rating or the credit rating of certain of NiSource’s subsidiaries;
NiSource’s ability to execute its growth strategy; changes in general economic, capital and commodity market conditions; pension funding obligations; economic
regulation and the impact of regulatory rate reviews; NiSource’s ability to obtain expected financial or regulatory outcomes; NiSource’s ability to adapt to,
and manage costs related to, advances in technology; any changes in our assumptions regarding the financial implications of the Greater Lawrence Incident;
compliance with the agreements entered into with the U.S. Attorney’s Office for the District of Massachusetts to settle the U.S. Attorney’s Office investigation
relating to the Greater Lawrence Incident; the pending sale of the Columbia Gas of Massachusetts business, including the terms and closing conditions under
the asset purchase agreement; potential incidents and other operating risks associated with our business; our ability to obtain sufficient insurance coverage;
the outcome of legal and regulatory proceedings, investigations, incidents, claims and litigation; any damage to NiSource’s reputation, including in connection
with the Greater Lawrence Incident; compliance with environmental laws and the costs of associated liabilities; fluctuations in demand from residential and
commercial customers; economic conditions of certain industries; the success of NIPSCO’s electric generation strategy; the price of energy commodities and
related transportation costs; the reliability of customers and suppliers to fulfill their payment and contractual obligations; potential impairments of goodwill or
definite-lived intangible assets; changes in taxation and accounting principles; the impact of an aging infrastructure; the impact of climate change; potential cyber-
attacks; construction risks and natural gas costs and supply risks; extreme weather conditions; the attraction and retention of a qualified work force; the ability of
NiSource’s subsidiaries to generate cash; NiSource’s ability to manage new initiatives and organizational changes; the performance of third-party suppliers and
service providers; changes in the method for determining LIBOR and the potential replacement of the LIBOR benchmark interest rate; and other matters set forth
in Item 1A, “Risk Factors” section of NiSource’s Annual Report on Form 10-K for the fiscal year ended December 31, 2019, and in other filings with the Securities
and Exchange Commission. A credit rating is not a recommendation to buy, sell or hold securities, and may be subject to revision or withdrawal at any time by the
assigning rating organization. In addition, dividends are subject to board approval. All forward-looking statements are expressly qualified in their entirety by the
foregoing cautionary statements. NiSource expressly disclaims any duty to update, supplement or amend any of its forward-looking statements contained in this
press release, whether as a result of new information, subsequent events or otherwise, except as required by applicable law.
Regulation G Disclosure Statement
This document includes financial results and guidance for NiSource with respect to net operating earnings available to common shareholders, which is a non-
GAAP financial measure as defined by the SEC’s Regulation G. The company includes this measure because management believes it permits investors to view
the company’s performance using the same tools that management uses and to better evaluate the company’s ongoing business performance. With respect to
such guidance, it should be noted that there will likely be a difference between this measure and its GAAP equivalent due to various factors, including, but not
limited to, fluctuations in weather, the impact of asset sales and impairments, and other items included in GAAP results. The company is not able to estimate the
impact of such factors on GAAP earnings and, as such, is not providing earnings guidance on a GAAP basis.
Investor Relations
(614) 460-4638
Media Relations
(614) 460-5544
media@nisource.com
Anticipated Dividend Record and
Payment Dates (NiSource common stock)
Record Date
02/11/20
04/30/20
07/31/20
10/30/20
02/09/21
Payment Date
02/20/20
05/20/20
08/20/20
11/20/20
02/19/21
Common Stock Dividend Declared
On February 20, 2020, the company paid a quarterly
dividend of $0.21 per share to stockholders of
record as of the close of business on February 11,
2020, equivalent to $0.84 per share on an annual
basis. Dividends are subject to board approval.
Stockholder Services
Questions about stockholder accounts, stock
certificates, transfer of shares, dividend payments,
automatic dividend reinvestment and stock purchase
plan, and electronic deposit may be directed to
Computershare at the following:
Computershare
c/o Shareholder Services
P.O. Box 505000
Louisville, Kentucky 40233
(888) 884-7790
• TDD for Hearing Impaired: (800) 231-5469
• Foreign Stockholders: (201) 680-6578
• TDD Foreign Stockholders: (201) 680-6610
• Computershare.com/investor
Investor and Financial Information
Financial analysts and investment professionals should direct written and
telephone inquiries to NiSource Investor Relations, 801 East 86th Avenue,
Merrillville, Indiana 46410 or (614) 460-4638. Copies of NiSource’s financial
reports are available at NiSource.com, or by writing or calling the Investor
Relations department at the address or phone number listed above.
Stock Listing
NiSource Inc. common stock is listed on the New York Stock Exchange
under the ticker symbol “NI.”
Annual Meeting
The 2020 Annual Meeting of Shareholders will be held at 10:00 a.m., Central
Time, on Tuesday, May 19, 2020, at The Rose Hotel Chicago O’Hare, 5200 Pearl
Street, Rosemont, Illinois 60018. All shareholders of record, as of March 24,
2020, are invited to attend. A formal notice of meeting, proxy statement and proxy
have been mailed or made available electronically to shareholders of record.
Independent Registered Public Accounting Firm
Deloitte & Touche
Sustainability
While addressed in the 2019 Integrated Annual Report, additional details on
sustainability and environmental, social and governance (ESG) issues and
related policies can be found under the Sustainability tab at www.nisource.com.
Board of Directors
Communications with the Board of Directors may
be made generally, to any director individually, to
the non-management directors as a group or the
lead director of the non-management group by
writing to the following address:
NiSource Inc.
Attention: Board of Directors or any
Board Member or non-management
directors or Chairman
c/o Corporate Secretary
801 East 86th Avenue
Merrillville, Indiana 46410
Corporate Governance
At www.nisource.com,
shareholders can view
the company’s corporate
governance guidelines, code
of business conduct, political
spending policy and charters
of all board-level committees.
Copies of these documents
are available to shareholders
without charge upon written
request to Corporate Secretary
at the above address.
COMPANY
LOCATIONS
Corporate Headquarters
NiSource Inc.
801 E. 86th Avenue
Merrillville, Indiana 46410
(219) 647-5990
NiSource Corporate Services
240 W. Nationwide Boulevard
Columbus, Ohio 43215
(614) 460-6000
Columbia Gas of Kentucky
2001 Mercer Road
Lexington, Kentucky 40511
Emergency: (800) 432-9515
Customer Care: (800) 432-9345
ColumbiaGasKY.com
Columbia Gas of Maryland
121 Champion Way
Canonsburg, Pennsylvania 15317
Emergency: (888) 460-4332
Customer Care: (888) 460-4332
ColumbiaGasMD.com
Columbia Gas of Massachusetts
4 Technology Drive
Westborough, Massachusetts 01581
Emergency: (800) 525-8222
Customer Care: (800) 688-6160
ColumbiaGasMA.com
Columbia Gas of Ohio
290 W. Nationwide Boulevard
Columbus, Ohio 43215
Emergency: (800) 344-4077
Customer Care: (800) 344-4077
ColumbiaGasOhio.com
Columbia Gas of Pennsylvania
121 Champion Way
Canonsburg, Pennsylvania 15317
Emergency: (888) 460-4332
Customer Care: (888) 460-4332
ColumbiaGasPA.com
Columbia Gas of Virginia
1809 Coyote Drive
Chester, Virginia 2383
Emergency: (800) 544-5606
Customer Care: (800) 543-8911
ColumbiaGasVA.com
NIPSCO
801 E. 86th Avenue
Merrillville, Indiana 46410
(800) 4NIPSCO
NIPSCO.com
NiSource is a trademark of NiSource Inc. All other trademarks are the property of their
respective owners. Further information about NiSource and its subsidiary companies can be found
at www.nisource.com. Information made available on our website does not constitute a part of this report.
© 2020 NiSource Inc. This report is printed on recycled paper.