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
(Exact name of registrant as specified in its charter)
(State or other jurisdiction of incorporation or organization) | (I.R.S. Employer Identification No.) | ||
(Address of principal executive offices) | (Zip Code) | ||
(Registrant’s telephone number, including area code)
Securities registered pursuant to Section 12(b) of the Act:
Title of Each Class | Trading Symbol(s) | Name of Each Exchange on Which Registered |
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
Indicate by check mark if the registrant is a well-known seasoned issuer, as defined in Rule 405 of the Securities Act. Yes þ 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 þ
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.
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).
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.
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 þ
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.
CONTENTS
Page No. | ||
Item 1. | ||
Item 1A. | ||
Item 1B. | ||
Item 2. | ||
Item 3. | ||
Item 4. | ||
Item 5. | ||
Item 6. | ||
Item 7. | ||
Item 7A. | ||
Item 8. | ||
Item 9. | ||
Item 9A. | ||
Item 9B. | ||
Item 10. | ||
Item 11. | ||
Item 12. | ||
Item 13. | ||
Item 14. | ||
Item 15. | ||
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DEFINED TERMS
The following is a list of abbreviations or acronyms that are used in this report:
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 | Columbia Gas of Virginia, Inc. | |
Company | NiSource Inc. and its subsidiaries, unless otherwise indicated 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 | Allowance for funds used during construction | |
AMR | Automatic meter reading | |
AMRP | Accelerated Main Replacement Program | |
AMT | Alternative Minimum Tax | |
AOCI | Accumulated Other Comprehensive Income | |
ASC | Accounting Standards Codification | |
ASU | Accounting Standards Update | |
ATM | At-the-market | |
Board | Board of Directors | |
BTA | Build-transfer agreement | |
CAP | Compliance Assurance Process | |
CCGT | Combined Cycle Gas Turbine | |
CCRs | Coal Combustion Residuals | |
CEP | Capital Expenditure Program | |
CERCLA | Comprehensive Environmental Response Compensation and Liability Act (also known as Superfund) | |
DPA | Deferred prosecution agreement | |
DPU | Department of Public Utilities | |
DSIC | Distribution System Investment Charge | |
DSM | Demand Side Management | |
ECT | Environmental Cost Tracker | |
EERM | Environmental Expense Recovery Mechanism | |
ELG | Effluent Limitation Guidelines | |
EPA | United States Environmental Protection Agency | |
EPS | Earnings per share | |
FAC | Fuel adjustment clause | |
FASB | Financial Accounting Standards Board | |
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DEFINED TERMS | ||
FERC | Federal Energy Regulatory Commission | |
FMCA | Federally Mandated Cost Adjustment | |
GAAP | Generally Accepted Accounting Principles | |
GCA | Gas cost adjustment | |
GCR | Gas cost recovery | |
GHG | Greenhouse gas | |
GSEP | Gas System Enhancement Program | |
GWh | Gigawatt hours | |
IRIS | Infrastructure Replacement and Improvement Surcharge | |
IRP | Infrastructure Replacement Program | |
IRS | Internal Revenue Service | |
IURC | Indiana Utility Regulatory Commission | |
LDCs | Local distribution companies | |
LIBOR | London inter-bank offered rate | |
LIFO | Last-in, first-out | |
MA DOR | Massachusetts Department of Revenue | |
Massachusetts Business | All of the assets being sold to, and liabilities being assumed by, Eversource pursuant to the Asset Purchase Agreement | |
MGP | Manufactured Gas Plant | |
MISO | Midcontinent Independent System Operator | |
MMDth | Million dekatherms | |
MW | Megawatts | |
MWh | Megawatt hours | |
NOL | Net Operating Loss | |
NTSB | National Transportation Safety Board | |
NYMEX | The New York Mercantile Exchange | |
NYSE | The New York Stock Exchange | |
OPEB | Other Postretirement and Postemployment Benefits | |
PCB | Polychlorinated biphenyls | |
PHMSA | U.S. Department of Transportation Pipeline and Hazardous 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 | |
PUCO | Public Utilities Commission of Ohio | |
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. | |
SEC | Securities and Exchange Commission | |
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DEFINED TERMS | ||
SMRP | Safety Modification and Replacement Program | |
STRIDE | Strategic Infrastructure Development and Enhancement | |
Sugar Creek | Sugar Creek electric generating plant | |
TCJA | Tax Cuts and Jobs Act of 2017 | |
TDSIC | Transmission, Distribution and Storage System Improvement Charge | |
U.S. Attorney's Office | U.S. Attorney's Office for the District of Massachusetts | |
VSCC | Virginia State Corporation Commission | |
WCE | Whiting Clean Energy | |
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.
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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.
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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
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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.
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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
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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.
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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.
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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,
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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.
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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
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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.
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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%.
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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.
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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
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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
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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.
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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.
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The following is a list of our executive officers, including their names, ages, offices held and other recent business experience.
Name | Age | Office(s) Held in Past 5 Years | |||
Joseph Hamrock | 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. | |||||
Vice President and Chief Financial Officer of UGI Utilities, a division of UGI Corporation (gas and electric utility company) from 2010 to March 2015. | |||||
Peter T. Disser | 51 | Vice President, Internal Audit of NiSource since January 2019. | |||
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. | |||
Vice President, Talent and Organizational Effectiveness of NiSource Corporate Services Company from June 2012 to July 2019. | |||||
Charles E. Shafer, II | 50 | Senior Vice President and Chief Safety Officer of NiSource since October 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. | |||
Senior Vice President and Chief Information Officer of NiSource from May 2014 to June 2015. | |||||
Suzanne K. Surface | 55 | Chief Services Officer of NiSource since January 2019. | |||
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. | |||||
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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.
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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.
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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: | |||||||||||||||||||