☐ TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d)
OF THE SECURITIES EXCHANGE ACT OF 1934
For the transition period from to
Commission file number 001-16189
NiSource Inc.
(Exact name of registrant as specified in its charter)
DE
35-2108964
(State or other jurisdiction of incorporation or organization)
(I.R.S. Employer Identification No.)
801 East 86th Avenue
Merrillville,
IN
46410
(Address of principal executive offices)
(Zip Code)
(877)647-5990
(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
Common Stock, par value $0.01 per share
NI
NYSE
Depositary Shares, each representing a 1/1,000th ownership interest in a share of 6.50% Series B
NI PR B
NYSE
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
Series A Corporate Units
NIMC
NYSE
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.
Yesþ No ¨
Indicate by check mark whether the registrant has submitted electronically every Interactive Data File required to be submitted pursuant to Rule 405 of Regulation S-T (232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit such files.)
Yesþ No ¨
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 definitions of "large accelerated filer," "accelerated filer," "smaller reporting company," and "emerging growth company" in Rule 12b-2 of the Exchange Act.
Large accelerated filerþ Accelerated filer ¨Emerging growth company ☐Non-accelerated filer ¨Smaller reporting company ☐
If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. ☐
Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act).
Yes ☐ No ☑
Indicate the number of shares outstanding of each of the issuer’s classes of common stock, as of the latest practicable date: Common Stock, $0.01 Par Value: 392,410,381 shares outstanding at July 26, 2021.
The following is a list of frequently used abbreviations or acronyms that are found in this report:
NiSource Subsidiaries and Affiliates
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.
NIPSCO
Northern Indiana Public Service Company LLC
NiSource ("we," "us" or "our")
NiSource Inc.
Rosewater
Rosewater Wind Generation LLC and its wholly owned subsidiary, Rosewater Wind Farm LLC
Abbreviations and Other
ACE
Affordable Clean Energy
AFUDC
Allowance for funds used during construction
AOCI
Accumulated Other Comprehensive Income (Loss)
ASC
Accounting Standards Codification
ASU
Accounting Standards Update
ATM
At-the-market
BTA
Build-transfer agreement
CCRs
Coal Combustion Residuals
CEP
Capital Expenditure Program
CERCLA
Comprehensive Environmental Response Compensation and Liability Act (also known as Superfund)
Corporate Units
Series A Corporate Units
COVID-19 ("the COVID-19 pandemic" or "the pandemic")
Novel Coronavirus 2019
DSIC
Distribution System Improvement Charge
DPU
Department of Public Utilities
EPA
United States Environmental Protection Agency
EPS
Earnings per share
Equity Units
Series A Equity Units
FAC
Fuel adjustment clause
FMCA
Federally Mandated Cost Adjustment
GAAP
Generally Accepted Accounting Principles
GCA
Gas cost adjustment
GHG
Greenhouse gases
GWh
Gigawatt hours
HLBV
Hypothetical Liquidation at Book Value
IRP
Infrastructure Replacement Program
IURC
Indiana Utility Regulatory Commission
LIBOR
London InterBank Offered Rate
LIFO
Last In, First Out
3
DEFINED TERMS
Massachusetts Business
All of the assets sold to, and liabilities 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
NTSB
National Transportation Safety Board
NYMEX
New York Mercantile Exchange
OPEB
Other Postretirement Benefits
PHMSA
Pipeline and Hazardous Materials Safety Administration
PPA
Power Purchase Agreement
PSC
Public Service Commission
PUC
Public Utilities Commission
RCRA
Resource Conservation and Recovery Act
RFP
Request for proposals
SAVE
Steps to Advance Virginia's Energy Plan
SEC
Securities and Exchange Commission
SMRP
Safety Modification and Replacement Program
SMS
Safety Management System
STRIDE
Strategic Infrastructure Development Enhancement
TCJA
An Act to provide for reconciliation pursuant to titles II and V of the concurrent resolution on the budget for fiscal year 2018 (commonly known as the Tax Cuts and Jobs Act of 2017)
TDSIC
Transmission, Distribution and Storage System Improvement Charge
VIE
Variable Interest Entity
Note regarding forward-looking statements
This Quarterly Report on Form 10-Q 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. Expressions of future goals and expectations and similar expressions, including "may," "will," "should," "could," "would," "aims," "seeks," "expects," "plans," "anticipates," "intends," "believes," "estimates," "predicts," "potential," "targets," "forecast," and "continue," reflecting something other than historical fact are intended to identify forward-looking statements. 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 Quarterly Report on Form 10-Q include, among other things, our ability to execute our business plan or growth strategy, including utility infrastructure investments; potential incidents and other operating risks associated with our business; our ability to adapt to, and manage costs related to, advances in technology; impacts related to our aging infrastructure; our ability to obtain sufficient insurance coverage and whether such coverage will protect us against significant losses; the success of our electric generation strategy; construction risks and natural gas costs and supply risks; fluctuations in demand from residential and commercial customers; fluctuations in the price of energy commodities and related transportation costs or an inability to obtain an adequate, reliable and cost-effective fuel supply to meet customer demands; the attraction and retention of a qualified workforce and ability to maintain good labor relations; our ability to manage new initiatives and organizational changes; the performance of third-party suppliers and service providers; potential cyber-attacks; any damage to our reputation; any remaining liabilities or impact related to the sale of the Massachusetts Business; the impacts of natural disasters, potential
4
terrorist attacks or other catastrophic events; the impacts of climate change and extreme weather conditions; our debt obligations; any changes to our credit rating or the credit rating of certain of our subsidiaries; any adverse effects related to our equity units; adverse economic and capital market conditions or increases in interest rates; economic regulation and the impact of regulatory rate reviews; our ability to obtain expected financial or regulatory outcomes; continuing and potential future impacts from the COVID-19 pandemic; economic conditions in certain industries; the reliability of customers and suppliers to fulfill their payment and contractual obligations; the ability of our subsidiaries to generate cash; pension funding obligations; potential impairments of goodwill; changes in the method for determining LIBOR and the potential replacement of the LIBOR benchmark interest rate; the outcome of legal and regulatory proceedings, investigations, incidents, claims and litigation; potential remaining liabilities related to 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; compliance with applicable laws, regulations and tariffs; compliance with environmental laws and the costs of associated liabilities; changes in taxation; other matters in the “Risk Factors” section of our Annual Report on Form 10-K for the fiscal year ended December 31, 2020, and in our Quarterly Report on Form 10-Q for the quarterly period ended March 31, 2021, 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.
Condensed Statements of Consolidated Comprehensive Income (Loss) (unaudited)
Three Months Ended June 30,
Six Months Ended June 30,
(in millions, net of taxes)
2021
2020
2021
2020
Net Income (Loss)
$
56.9
$
(4.7)
$
353.4
$
70.9
Other comprehensive income (loss):
Net unrealized gain (loss) on available-for-sale debt securities(1)
0.9
5.7
(1.6)
0.3
Net unrealized gain (loss) on cash flow hedges(2)
(49.8)
2.7
34.8
(130.6)
Unrecognized pension and OPEB benefit (costs)(3)
0.8
0.3
(0.1)
1.0
Total other comprehensive income (loss)
(48.1)
8.7
33.1
(129.3)
Comprehensive Income (Loss)
$
8.8
$
4.0
$
386.5
$
(58.4)
(1)Net unrealized gain (loss) on available-for-sale debt securities, net of $0.3 million and $1.5 million tax expense in the second quarter of 2021 and 2020, respectively, and $0.4 million tax benefit and $0.1 million tax expense for the six months ended 2021 and 2020, respectively.
(2)Net unrealized gain (loss) on cash flow hedges, net of $16.5 million tax benefit and $0.9 million tax expense in the second quarter of 2021 and 2020, respectively, and $11.5 million tax expense and $43.2 million tax benefit for the six months ended 2021 and 2020, respectively.
(3)Unrecognized pension and OPEB benefit (costs), net of $0.2 million tax expense in the second quarter of 2021 and 2020, and $1.1 million tax expense and $0.1 million tax benefit for the six months ended 2021 and 2020, respectively.
The accompanying Notes to Condensed Consolidated Financial Statements (unaudited) are an integral part of these statements.
Available-for-sale debt securities (amortized cost of $161.0 and $163.9, allowance for credit losses of $0.2 and $0.5, respectively)
166.3
170.9
Other investments
85.2
81.1
Total Investments and Other Assets
251.5
252.0
Current Assets
Cash and cash equivalents
77.5
116.5
Restricted cash
12.9
9.1
Accounts receivable
605.3
843.6
Allowance for credit losses
(41.6)
(52.3)
Accounts receivable, net
563.7
791.3
Gas inventory
148.8
191.2
Materials and supplies, at average cost
143.5
141.5
Electric production fuel, at average cost
38.6
68.4
Exchange gas receivable
31.7
34.1
Regulatory assets
180.1
135.7
Prepayments and other
187.4
171.6
Total Current Assets(1)
1,384.2
1,659.4
Other Assets
Regulatory assets
1,777.1
1,794.8
Goodwill
1,485.9
1,485.9
Deferred charges and other
260.0
228.9
Total Other Assets
3,523.0
3,509.6
Total Assets
$
22,313.8
$
22,040.5
(1)Includes $172.8 million and $175.6 million of net property, plant and equipment assets and $4.8 million and $1.7 million of current assets of a consolidated VIE as of June 30, 2021 and December 31, 2020 that may be used only to settle obligations of the consolidated VIE. Refer to Note 14 "Variable Interest Entities" for additional information.
The accompanying Notes to Condensed Consolidated Financial Statements (unaudited) are an integral part of these statements.
Condensed Statements of Consolidated Equity (unaudited)
(in millions)
Common Stock
Preferred Stock(1)
Treasury Stock
Additional Paid-In Capital
Retained Deficit
Accumulated Other Comprehensive Loss
Noncontrolling Interest in Consolidated Subsidiaries
Total
Balance as of April 1, 2021
$
3.9
$
880.0
$
(99.9)
$
6,892.9
$
(1,669.8)
$
(75.5)
$
94.1
$
6,025.7
Comprehensive Income:
Net income (loss)
—
—
—
—
60.3
—
(3.4)
56.9
Other comprehensive loss, net of tax
—
—
—
—
—
(48.1)
—
(48.1)
Dividends:
Common stock ($0.22 per share)
—
—
—
—
(86.4)
—
—
(86.4)
Preferred stock (See Note 5)
—
—
—
—
(8.2)
—
—
(8.2)
Distribution to noncontrolling interest
—
—
—
—
—
—
(0.3)
(0.3)
Stock issuances:
Equity Units
—
838.8
—
(173.3)
—
—
—
665.5
Employee stock purchase plan
—
—
—
1.2
—
—
—
1.2
Long-term incentive plan
—
—
—
4.8
—
—
—
4.8
401(k) and profit sharing
—
—
—
2.4
—
—
—
2.4
Balance as of June 30, 2021
$
3.9
$
1,718.8
$
(99.9)
$
6,728.0
$
(1,704.1)
$
(123.6)
$
90.4
$
6,613.5
(1)Series A, Series B, and Series C shares have an aggregate liquidation preference of $400M, $500M, and $863M, respectively. See Note 5, "Equity" for additional information.
(in millions)
Common Stock
Preferred Stock(1)
Treasury Stock
Additional Paid-In Capital
Retained Deficit
Accumulated Other Comprehensive Loss
Noncontrolling Interest in Consolidated Subsidiaries
Total
Balance as of January 1, 2021
$
3.9
$
880.0
$
(99.9)
$
6,890.1
$
(1,765.2)
$
(156.7)
$
85.6
$
5,837.8
Comprehensive Income:
Net income (loss)
—
—
—
—
355.8
—
(2.4)
353.4
Other comprehensive income, net of tax
—
—
—
—
—
33.1
—
33.1
Dividends:
Common stock ($0.66 per share)
—
—
—
—
(259.0)
—
—
(259.0)
Preferred stock (See Note 5)
—
—
—
—
(35.7)
—
—
(35.7)
Contribution from noncontrolling interest, net of distributions
—
—
—
—
—
—
7.2
7.2
Stock issuances:
Equity Units
—
838.8
—
(173.3)
—
—
—
665.5
Employee stock purchase plan
—
—
—
2.5
—
—
—
2.5
Long-term incentive plan
—
—
—
4.3
—
—
—
4.3
401(k) and profit sharing
—
—
—
4.7
—
—
—
4.7
ATM program
—
—
—
(0.3)
—
—
—
(0.3)
Balance as of June 30, 2021
$
3.9
$
1,718.8
$
(99.9)
$
6,728.0
$
(1,704.1)
$
(123.6)
$
90.4
$
6,613.5
(1)Series A, Series B, and Series C shares have an aggregate liquidation preference of $400M, $500M, and $863M, respectively. See Note 5, "Equity" for additional information.
Condensed Statements of Consolidated Equity (unaudited) (continued)
(in millions)
Common Stock
Preferred Stock(1)
Treasury Stock
Additional Paid-In Capital
Retained Deficit
Accumulated Other Comprehensive Loss
Noncontrolling Interest in Consolidated Subsidiaries
Total
Balance as of April 1, 2020
$
3.8
$
880.0
$
(99.9)
$
6,671.5
$
(1,483.4)
$
(230.6)
$
—
$
5,741.4
Comprehensive Income:
Net loss
—
—
—
—
(4.7)
—
—
(4.7)
Other comprehensive income, net of tax
—
—
—
—
—
8.7
—
8.7
Dividends:
Common stock ($0.21 per share)
—
—
—
—
(80.4)
—
—
(80.4)
Preferred stock (See Note 5)
—
—
—
—
(8.2)
—
—
(8.2)
Stock issuances:
Employee stock purchase plan
—
—
—
1.4
—
—
—
1.4
Long-term incentive plan
—
—
—
0.4
—
—
—
0.4
401(k) and profit sharing
—
—
—
3.2
—
—
—
3.2
Balance as of June 30, 2020
$
3.8
$
880.0
$
(99.9)
$
6,676.5
$
(1,576.7)
$
(221.9)
$
—
$
5,661.8
(1)Series A and Series B shares have an aggregate liquidation preference of $400M and $500M, respectively. See Note 5, "Equity" for additional information.
(in millions)
Common Stock
Preferred Stock(1)
Treasury Stock
Additional Paid-In Capital
Retained Deficit
Accumulated Other Comprehensive Loss
Noncontrolling Interest in Consolidated Subsidiaries
Total
Balance as of January 1, 2020
$
3.8
$
880.0
$
(99.9)
$
6,666.2
$
(1,370.8)
$
(92.6)
$
—
$
5,986.7
Comprehensive Income:
Net income
—
—
—
—
70.9
—
—
70.9
Other comprehensive loss, net of tax
—
—
—
—
—
(129.3)
—
(129.3)
Dividends:
Common stock ($0.63 per share)
—
—
—
—
(241.1)
—
—
(241.1)
Preferred stock (See Note 5)
—
—
—
—
(35.7)
—
—
(35.7)
Stock issuances:
Employee stock purchase plan
—
—
—
2.7
—
—
—
2.7
Long-term incentive plan
—
—
—
(0.1)
—
—
—
(0.1)
401(k) and profit sharing
—
—
—
7.7
—
—
—
7.7
Balance as of June 30, 2020
$
3.8
$
880.0
$
(99.9)
$
6,676.5
$
(1,576.7)
$
(221.9)
$
—
$
5,661.8
(1)Series A and Series B shares have an aggregate liquidation preference of $400M and $500M, respectively. See Note 5, "Equity" for additional information.
The accompanying Notes to Condensed Consolidated Financial Statements (unaudited) are an integral part of these statements.
Notes to Condensed Consolidated Financial Statements (unaudited)
1. Basis of Accounting Presentation
Our accompanying Condensed Consolidated Financial Statements (unaudited) reflect all normal recurring adjustments that are necessary, in the opinion of management, to present fairly the results of operations in accordance with GAAP in the United States of America. The accompanying financial statements include the accounts of us, our majority-owned subsidiaries, and VIEs of which we are the primary beneficiary after the elimination of all intercompany accounts and transactions.
The accompanying financial statements should be read in conjunction with the consolidated financial statements and notes thereto included in our Annual Report on Form 10-K for the fiscal year ended December 31, 2020. Income for interim periods may not be indicative of results for the calendar year due to weather variations and other factors.
The Condensed Consolidated Financial Statements (unaudited) have been prepared pursuant to the rules and regulations of the SEC. Certain information and note disclosures normally included in annual financial statements prepared in accordance with GAAP have been condensed or omitted pursuant to those rules and regulations, although we believe that the disclosures made in this Quarterly Report on Form 10-Q are adequate to make the information herein not misleading.
Notes to Condensed Consolidated Financial Statements (unaudited) (continued)
2. Recent Accounting Pronouncements
Recently Issued Accounting Pronouncements
We are currently evaluating the impact of certain ASUs on our Condensed Consolidated Financial Statements (unaudited) and Notes to Condensed Consolidated Financial Statements (unaudited), which are described below:
Standard
Description
Effective Date
Effect on the financial statements or other significant matters
ASU 2020-04,
Reference Rate Reform
(Topic 848):
Facilitation of the
Effects of Reference
Rate Reform on
Financial Statement
This pronouncement provides temporary optional expedients and exceptions for applying GAAP principles to contract modifications and hedging relationships to ease the financial reporting burdens of the expected market transition from LIBOR and other interbank offered rates to alternative reference rates.
Upon issuance on
March 12, 2020, and
will apply through
December 31, 2022.
We continue to evaluate the temporary expedients and options available under this guidance, and the effects of this pronouncement on our Condensed Consolidated Financial Statements (unaudited) and Notes to Condensed Consolidated Financial Statements (unaudited). We are currently identifying and evaluating contracts that may be impacted. As of June 30, 2021, we have not applied any expedients and options available under this ASU.
ASU 2020-06, Debt with Conversion and Other Options (Subtopic 470-20) and Derivative and Hedging - Contracts in Entity's Own Equity (Subtopic 815-40): Accounting for Convertible Instruments and Contracts in an Entity's Own Equity
This pronouncement simplifies the accounting for certain financial instruments with characteristics of liabilities and equity, including convertible instruments and contracts on an entity's own equity. Specifically, the ASU "simplifies accounting for convertible instruments by removing major separation models required under current GAAP." In addition, the ASU "removes certain settlement conditions that are required for equity contracts to qualify for it" and "simplifies the diluted earnings per share (EPS) calculations in certain areas."
Annual period beginning after December 15, 2021, and interim periods within those fiscal years.
This accounting pronouncement will impact the denominator in the calculation of diluted EPS for our Series A Equity Units. Beginning Q1 2022, we will be required to assume share settlement of the remaining purchase contract liability balance when applying the if-converted method. Moreover, we will also be required to utilize the average share price for the period instead of the end of period price. We will adopt this ASU on its effective date.
Recently Adopted Accounting Pronouncements
Standard
Adoption
ASU 2019-12, Income Taxes (Topic 740): Simplifying the Accounting for Income Taxes
This pronouncement simplifies the accounting for income taxes by eliminating certain exceptions to the general principles in ASC 740, income taxes. It also improves consistency of application for other areas of the guidance by clarifying and amending existing guidance. We adopted the amendments of this pronouncement as of January 1, 2021 with no material impact to the Condensed Consolidated Financial Statements (unaudited).
3. Revenue Recognition
Revenue Disaggregation and Reconciliation. We disaggregate revenue from contracts with customers based upon reportable segment, as well as by customer class. The Gas Distribution Operations segment provides natural gas service and transportation for residential, commercial and industrial customers in Ohio, Pennsylvania, Virginia, Kentucky, Maryland, and Indiana. The Electric Operations segment provides electric service in 20 counties in the northern part of Indiana.
Notes to Condensed Consolidated Financial Statements (unaudited) (continued)
The tables below reconcile revenue disaggregation by customer class to segment revenue, as well as to revenues reflected on the Condensed Statements of Consolidated Income (Loss) (unaudited) for the three and six months ended June 30, 2021 and June 30, 2020:
Three Months Ended June 30, 2021
(in millions)
Gas Distribution Operations
Electric Operations
Corporate and Other(2)
Total
Customer Revenues(1)
Residential
$
378.6
$
131.9
$
—
$
510.5
Commercial
125.4
130.0
—
255.4
Industrial
44.0
119.0
—
163.0
Off-system
17.0
—
—
17.0
Miscellaneous
4.9
1.4
0.2
6.5
Total Customer Revenues
$
569.9
$
382.3
$
0.2
$
952.4
Other Revenues
4.4
21.2
8.0
33.6
Total Operating Revenues
$
574.3
$
403.5
$
8.2
$
986.0
(1)Customer revenue amounts exclude intersegment revenues. See Note 19, "Business Segment Information," for discussion of intersegment revenues.
(2)Other revenues related to the Transition Services Agreement entered into in connection with the sale of the Massachusetts Business.
Three Months Ended June 30, 2020
(in millions)
Gas Distribution Operations
Electric Operations
Corporate and Other
Total
Customer Revenues(1)
Residential
$
414.7
$
127.5
$
—
$
542.2
Commercial
122.7
112.9
—
235.6
Industrial
48.6
89.3
—
137.9
Off-system
8.0
—
—
8.0
Miscellaneous
5.3
3.5
0.2
9.0
Total Customer Revenues
$
599.3
$
333.2
$
0.2
$
932.7
Other Revenues
7.0
23.0
—
30.0
Total Operating Revenues
$
606.3
$
356.2
$
0.2
$
962.7
(1)Customer revenue amounts exclude intersegment revenues. See Note 19, "Business Segment Information," for discussion of intersegment revenues.
Notes to Condensed Consolidated Financial Statements (unaudited) (continued)
Six Months Ended June 30, 2021
(in millions)
Gas Distribution Operations
Electric Operations
Corporate and Other(2)
Total
Customer Revenues(1)
Residential
$
1,152.1
$
261.1
$
—
$
1,413.2
Commercial
396.9
252.8
—
649.7
Industrial
101.9
241.9
—
343.8
Off-system
31.4
—
—
31.4
Miscellaneous
14.7
5.7
0.4
20.8
Total Customer Revenues
$
1,697.0
$
761.5
$
0.4
$
2,458.9
Other Revenues
13.1
44.5
15.1
72.7
Total Operating Revenues
$
1,710.1
$
806.0
$
15.5
$
2,531.6
(1)Customer revenue amounts exclude intersegment revenues. See Note 19, "Business Segment Information," for discussion of intersegment revenues.
(2)Other revenues related to the Transition Services Agreement entered into in connection with the sale of the Massachusetts Business.
Six Months Ended June 30, 2020
(in millions)
Gas Distribution Operations
Electric Operations
Corporate and Other
Total
Customer Revenues(1)
Residential
$
1,211.2
$
246.7
$
—
$
1,457.9
Commercial
392.1
233.1
—
625.2
Industrial
122.8
198.4
—
321.2
Off-system
26.7
—
—
26.7
Miscellaneous
17.8
9.4
0.4
27.6
Total Customer Revenues
$
1,770.6
$
687.6
$
0.4
$
2,458.6
Other Revenues
63.7
45.9
—
109.6
Total Operating Revenues
$
1,834.3
$
733.5
$
0.4
$
2,568.2
(1)Customer revenue amounts exclude intersegment revenues. See Note 19, "Business Segment Information," for discussion of intersegment revenues.
Customer Accounts Receivable. Accounts receivable on our Condensed Consolidated Balance Sheets (unaudited) includes both billed and unbilled amounts, as well as certain amounts that are not related to customer revenues. Unbilled amounts of accounts receivable relate to a portion of a customer’s consumption of gas or electricity from the date of the last cycle billing through the last day of the month (balance sheet date). Factors taken into consideration when estimating unbilled revenue include historical usage, customer rates and weather. A significant portion of our operations are subject to seasonal fluctuations in sales. During the heating season, primarily from November through March, revenues and receivables from gas sales are more significant than in other months. The opening and closing balances of customer receivables for the six months ended June 30, 2021 are presented in the table below. We had no significant contract assets or liabilities during the period. Additionally, we have not incurred any significant costs to obtain or fulfill contracts.
Utility revenues are billed to customers monthly on a cycle basis. We expect that substantially all customer accounts receivable will be collected following customer billing, as this revenue consists primarily of periodic, tariff-based billings for service and usage. We maintain common utility credit risk mitigation practices, including requiring deposits and actively pursuing collection of past due amounts. Our regulated operations also utilize certain regulatory mechanisms that facilitate recovery of bad debt costs within tariff-based rates, which provides further evidence of collectibility. It is probable that substantially all of the consideration to which we are entitled from customers will be collected upon satisfaction of performance obligations.
Notes to Condensed Consolidated Financial Statements (unaudited) (continued)
Allowance for Credit Losses. To evaluate for expected credit losses, customer account receivables are pooled based on similar risk characteristics, such as customer type, geography, payment terms, and related macro-economic risks. Expected credit losses are established using a model that considers historical collections experience, current information, and reasonable and supportable forecasts. Relevant and reliable internal and external inputs used in the model include, but are not limited to, energy consumption trends, revenue projections, actual charge-offs data, recoveries data, shut-offs, and final bill data. We continuously evaluate available reasonable and supportable information relevant to assessing collectability of current and future receivables. We evaluate creditworthiness of specific customers periodically or when required by changes in facts and circumstances. When we become aware of a specific commercial or industrial customer's inability to pay, an allowance for expected credit losses is recorded for the relevant amount. We also monitor other circumstances that could affect our overall expected credit losses; these include, but are not limited to, creditworthiness of overall population in service territories, adverse conditions impacting an industry sector, and current economic conditions.
At each reporting period, we record expected credit losses using an allowance for credit losses account. When deemed to be uncollectible, customer accounts are written-off. A rollforward of our allowance for credit losses as of June 30, 2021 and December 31, 2020 are presented in the table below:
(in millions)
Gas Distribution Operations
Electric Operations
Corporate and Other
Total
Balance as of January 1, 2021
$
41.8
$
9.7
$
0.8
$
52.3
Current period provisions
5.1
0.4
—
5.5
Write-offs charged against allowance
(18.3)
(4.9)
—
(23.2)
Recoveries of amounts previously written off
6.8
0.2
—
7.0
Balance as of June 30, 2021
$
35.4
$
5.4
$
0.8
$
41.6
(in millions)
Gas Distribution Operations
Electric Operations
Corporate and Other
Total
Balance as of January 1, 2020
9.1
3.1
0.8
13.0
Current period provisions
45.3
9.3
—
54.6
Write-offs charged against allowance
(26.7)
(3.0)
—
(29.7)
Recoveries of amounts previously written off
14.1
0.3
—
14.4
Balance as of December 31, 2020
41.8
9.7
0.8
52.3
In connection with the COVID-19 pandemic, certain state regulatory commissions instituted regulatory moratoriums that impacted our ability to pursue our standard credit risk mitigation practices. Following the issuance of these moratoriums, certain of our regulated operations have been authorized to recognize a regulatory asset for bad debt costs above levels currently in rates. We have reinstated our common credit mitigation practices where moratoriums have expired (see Note 8, "Regulatory Matters," for additional information on regulatory moratoriums and regulatory assets). As of June 30, 2021, we have also evaluated the adequacy of our allowance for credit losses in light of the shut-off moratoriums due to the COVID-19 pandemic that remain in effect for Columbia of Virginia and Columbia of Maryland. Our evaluation included an analysis of customer payment trends in 2020, economic conditions, receivables aging, considerations of past economic downturns and the associated allowance for credit losses and customer account write-offs. In addition, we considered benefits available under governmental COVID-19 relief programs, the impact of unemployment benefits initiatives, and flexible payment plans being offered to customers affected by or experiencing hardship as a result of the pandemic, which could help to mitigate the potential for increasing customer account delinquencies. Based upon this evaluation, we have concluded that the allowance for credit losses as of June 30, 2021 adequately reflected the collection risk and net realizable value for our receivables. We will continue to monitor changing circumstances and will adjust our allowance for credit losses accordingly.
Notes to Condensed Consolidated Financial Statements (unaudited) (continued)
4. Earnings Per Share
The calculations of basic and diluted earnings per share are based on the weighted average number of shares of common stock and potential common stock outstanding during the period. For the purposes of determining diluted earnings per share, the effects of the purchase contracts included within the Series A Equity Units were included in the calculation of potential common stock outstanding for the three and six months ended June 30, 2021 using the if-converted method under US GAAP. This method assumes conversion at the beginning of the reporting period, or at time of issuance, if later. For the purchase contracts, the number of shares of our common stock that would be issuable at the end of each reporting period will be reflected in the denominator of our diluted EPS calculation. If the stock price falls below the initial reference price of $24.51, the number of shares of our common stock used in calculating diluted EPS will be the maximum number of shares per the contract as described in Note 5, "Equity." Conversely, if the stock price is above the initial reference price of $24.51, a variable number of shares of our common stock will be used in calculating diluted EPS. A numerator adjustment was reflected in the calculation of diluted EPS for interest expense incurred in 2021, net of tax, related to the purchase contracts.
The Series C Mandatory Convertible Preferred Stock included within the Series A Equity Units represent contingently convertible securities as the conversion is contingent on a successful remarketing as described in Note 5, "Equity." Contingently convertible shares where conversion is not tied to a market price trigger are excluded from the calculation of diluted EPS until such time as the contingency has been resolved under the if-converted method. As of June 30, 2021, the contingency was not resolved and thus no shares were reflected in the denominator in the calculation of diluted EPS for the three and six months ended June 30, 2021.
Diluted EPS also includes the incremental effects of the various long-term incentive compensation plans and the ATM forward agreements under the treasury stock method when the impact would be dilutive. Refer to Note 5, "Equity," for more information on our ATM forward agreements.
For the three months ended June 30, 2020, we had a net loss on the Condensed Statements of Consolidated Income (Loss) (unaudited) during the period, and any potentially dilutive shares would have had an anti-dilutive impact on EPS. The following table presents the calculation of our basic and diluted EPS:
Three Months Ended June 30,
Six Months Ended June 30,
(in millions, except per share amounts)
2021
2020
2021
2020
Numerator:
Net Income (Loss) Available to Common Shareholders - Basic
46.5
(18.5)
328.2
43.3
Dilutive effect of Series A Equity Units
0.4
—
0.4
—
Net Income (Loss) Available to Common Shareholders - Diluted
46.9
(18.5)
328.6
43.3
Denominator:
Average common shares outstanding - Basic
393.0
383.5
392.8
383.3
Dilutive potential common shares:
Series A Equity Units
28.2
—
14.2
—
Shares contingently issuable under employee stock plans
Notes to Condensed Consolidated Financial Statements (unaudited) (continued)
5. Equity
ATM Program and Forward Sale Agreements. On February 22, 2021, we entered into six separate equity distribution agreements pursuant to which we are able to sell up to an aggregate of $750.0 million of our common stock.
On February 23, 2021, under the ATM program, we executed a forward agreement, which allows us to issue a fixed number of shares at a price to be settled in the future. From February 24, 2021 to March 17, 2021, we borrowed 6,672,740 shares from third parties, which the dealer sold at a weighted average price of $22.48 per share. We may settle this agreement in shares, cash, or net shares by December 15, 2021. Had we settled all the shares under the forward agreement at June 30, 2021, we would have received approximately $146.7 million, based on a net price of $21.99 per share.
On June 1, 2021, under the ATM program, we executed a forward agreement, which allows us to issue a fixed number of shares at a price to be settled in the future. From June 1, 2021 to June 11, 2021, we borrowed 5,852,475 shares from third parties, which the dealer sold at a weighted average price of $25.63 per share. We may settle this agreement in shares, cash, or net shares by December 15, 2021. Had we settled all the shares under the forward agreement at June 30, 2021, we would have received approximately $148.4 million, based on a net price of $25.36 per share.
As of June 30, 2021, the ATM program (including the impacts of the forward sale agreements discussed above) had approximately $450.0 million of equity available for issuance. The program expires on December 31, 2023.
Preferred Stock. As of June 30, 2021, we had 20,000,000 shares of preferred stock authorized for issuance, of which 1,302,500 shares of preferred stock in the aggregate for all series were outstanding. The following table displays preferred dividends declared for the period by outstanding series of shares:
Three Months Ended June 30,
Six Months Ended June 30,
June 30
December 31,
2021
2020
2021
2020
2021
2020
(in millions except shares and per share amounts)
Liquidation Preference Per Share
Shares
Dividends Declared Per Share
Outstanding
5.650% Series A
$
1,000.00
400,000
—
—
28.25
28.25
$
393.9
$
393.9
6.500% Series B
$
25,000.00
20,000
406.25
406.25
1,218.75
1,218.75
$
486.1
$
486.1
Series C(1)
$
1,000.00
862,500
—
—
—
—
$
838.8
$
—
(1)The Series C Mandatory Convertible Preferred Stock initially will not bear any dividends.
In addition, 20,000 shares of Series B–1 Preferred Stock, par value $0.01 per share, were outstanding as of June 30, 2021. Holders of Series B–1 Preferred Stock are not entitled to receive dividend payments and have no conversion rights. The Series B–1 Preferred Stock is paired with the Series B Preferred Stock and may not be transferred, redeemed or repurchased except in connection with the simultaneous transfer, redemption or repurchase of the underlying Series B Preferred Stock.
As of June 30, 2021 and 2020, Series A Preferred Stock had $1.0 million of cumulative preferred dividends in arrears, or $2.51 per share, and Series B Preferred Stock had $1.4 million of cumulative preferred dividends in arrears, or $72.23 per share.
Series A Equity Units. On April 19, 2021, we completed the sale of 8.625 million Series A Equity Units, initially consisting of Series A Corporate Units, each with a stated amount of $100. The offering generated net proceeds of $835.5 million, after underwriting and issuance expenses. Each Corporate Unit consists of a forward contract to purchase shares of our common stock in the future and a 1/10th, or 10%, undivided beneficial ownership interest in one share of Series C Mandatory Convertible Preferred Stock, par value $0.01 per share, with a liquidation preference of $1,000 per share.
The purchase contract obligates holders to purchase shares of our common stock on December 1, 2023, subject to early settlement in certain situations.The purchase price paid under the purchase contract is $100 and the number of shares to be purchased will be determined under a settlement rate formula based on the volume-weighted average share price of our common stock near the settlement date, subject to a maximum settlement rate. The Series C Mandatory Convertible Preferred Stock will initially be pledged upon issuance as collateral to secure the purchase of common stock under the related purchase contracts.
We will pay quarterly contract adjustment payments at the rate of 7.75% per year on the stated amount of $100 per Equity Unit.
Notes to Condensed Consolidated Financial Statements (unaudited) (continued)
The contract adjustment payments are payable in cash, shares of our common stock or a combination thereof, at our election. We have the right to defer the payment of contract adjustment payments until no later than the purchase contract settlement date. If we exercise our option to defer the payment of contract adjustment payments, then until the deferred contract adjustment payments have been paid, we will not declare or pay any dividends on, or make any distributions on, or redeem, purchase or acquire, or make a liquidation payment with respect to, any shares of our capital stock; make any payment of principal of, or interest or premium, if any, on, or repay, repurchase or redeem any of our debt securities that rank on parity with, or junior to, the contract adjustment payments; or make any guarantee payments under any guarantee by us of securities of any of our subsidiaries if our guarantee ranks on parity with, or junior to, the contract adjustment payments.
The Series C Mandatory Convertible Preferred Stock initially will not bear any dividends and the liquidation preference of the mandatory convertible preferred stock will not accrete. The Series C Mandatory Convertible Preferred Stock is expected to be remarketed prior to December 1, 2023. Following a successful remarketing, dividends may become payable on the Series C Mandatory Convertible Preferred Stock and/or the minimum conversion rate of the Series C Mandatory Convertible Preferred Stock may be increased. Each share of Series C Mandatory Convertible Preferred Stock, unless previously converted, will automatically convert based on a conversion rate on the mandatory conversion date, which is expected to be on or about March 1, 2024. The conversion rate will be determined based on the volume-weighted average share price of our common stock near the conversion date, subject to a minimum and maximum conversion rate. If no successful remarketing of the Series C Mandatory Convertible Preferred Stock has previously occurred, effective as of December 1, 2023, the conversion rate will be zero, no shares of our common stock will be delivered upon automatic conversion and each share of Series C Mandatory Convertible Preferred Stock will be automatically transferred to us on the mandatory conversion date without any payment of cash or shares of our common stock thereon. In the event of such a remarketing failure, any shares of Series C Mandatory Convertible Preferred Stock held as part of Corporate Units will be automatically delivered to us on December 1, 2023 in full satisfaction of the relevant holder's obligation under the related purchase contracts.
We have recorded the present value of the purchase contract payments as a liability with a corresponding reduction to additional-paid-in-capital. The current portion of this liability is included in "Other accruals," and the noncurrent portion is included in "Other noncurrent liabilities" on the Condensed Consolidated Balance Sheets (unaudited). Purchase contract payments are recorded against this liability. Accretion of the stock purchase contract liability is recorded as interest expense. Refer to Note 4,"Earnings Per Share," for additional information regarding our application of diluted EPS to the purchase contracts and the Series C Mandatory Convertible Preferred Stock. Under the terms of the Series A Equity Units, assuming no anti-dilution or other adjustments, the maximum number of shares of common stock we will issue under the purchase contracts is 35.2 million and maximum number of shares of common stock we will issue under the Series C Mandatory Convertible Preferred Stock is 35.2 million.
Selected information about the Series A Equity Units is presented below:
(in millions except contract rate)
Issuance Date
Units Issued
Total Net Proceeds(1)
Purchase Contract Annual Rate
Purchase Contract Liability(2)
Series A Equity Units
April 19, 2021
8.625
$
835.5
7.75
%
$
168.8
(1)Issuance costs of $27 million were recorded on a relative fair value basis as a reduction to preferred stock of $22.5 million and a reduction to the purchase contract liability of $4.5 million.
(2)A cash payment of $7.8 million was made during the three and six months ended June 30, 2021. The purchase contract liability was $161.5 million at June 30, 2021.
6. Gas in Storage
We use both the LIFO inventory methodology and the weighted-average cost methodology to value natural gas in storage. Gas Distribution Operations prices natural gas storage injections at the average of the costs of natural gas supply purchased during the year. For interim periods, the difference between current projected replacement cost and the LIFO cost for quantities of gas temporarily withdrawn from storage is recorded as a temporary LIFO liquidation credit or debit within the Condensed Consolidated Balance Sheets (unaudited). Due to seasonality requirements, we expect interim variances in LIFO layers to be replenished by year end. We had a temporary LIFO liquidation debit of $9.8 million and zero as of June 30, 2021 and December 31, 2020, respectively, for certain gas distribution companies recorded within “Prepayments and other” on the Condensed Consolidated Balance Sheets (unaudited).
Notes to Condensed Consolidated Financial Statements (unaudited) (continued)
7. Property, Plant and Equipment
In 2020, MISO approved NIPSCO's plan to retire the R.M. Schahfer Generating Station in 2023. The December 2019 NIPSCO electric rate case order included approval to create a regulatory asset upon the retirement of the R.M. Schahfer Generating Station. The order allows for the recovery of and on the net book value of the station by the end of 2032. On March 11, 2021, NIPSCO submitted separate Attachment Y Notices for Units 14 and 15 seeking a suspension date of October 1, 2021 for both coal fired units at R.M. Schahfer Generating Station. On May 28, 2021, NIPSCO received approval from MISO to suspend and retire these two units on October 1, 2021. The remaining two units are still scheduled to be retired in 2023.
In connection with MISO's approvals of NIPSCO's planned retirement of the R.M. Schahfer Generating Station, we recorded plant retirement-related charges during 2020 comprised of write downs of certain capital projects that have been cancelled and materials and supplies inventory balances deemed obsolete due to the planned retirement. In addition, during the second quarter of 2021, we recorded $8.6 million of plant retirement-related charges, primarily related to obsolete inventory write downs. These charges are presented within "Operation and maintenance" on the Condensed Statements of Consolidated Income (Loss). At retirement, the net book value of the retired units will be reclassified from "Net Property, Plant and Equipment," to current and long-term “Regulatory Assets.” The total net book value of R.M. Schahfer Generating Station's coal units and other associated plant estimated to be retired was $823.1 million at June 30, 2021.
On April 28, 2021, in response to a Motion filed by certain parties in NIPSCO's quarterly FAC proceeding, the IURC created a sub-docket proceeding in order to receive additional information related to the planned retirements of Units 14 and 15 by the end of 2021 and any resulting cost impacts to customers. NIPSCO does not anticipate that the sub-docket proceeding will impact the planned timing of October 1, 2021 for the unit retirements.
8. Regulatory Matters
COVID-19 Regulatory Filings
In response to COVID-19, we received approvals or directives from the regulatory commissions in the states in which we operate. The ongoing impacts of these approvals or directives are described in the table below:
Jurisdiction
Moratorium in Place?
Regulatory Asset balance as of June 30, 2021
(in millions)
Deferred COVID-19 Costs
Columbia of Ohio
No
$
2.1
Incremental operation and maintenance expenses
NIPSCO
No
$
6.2
Incremental bad debt expense and the costs to implement the requirements of the COVID-19 related order
Columbia of Pennsylvania
No
$
7.1
Incremental bad debt expense incurred since March 13, 2020 above levels currently in rates
Columbia of Virginia
Yes
$
1.2
Incremental incurred costs (including incremental bad debt expense), subject to an earnings test review
Columbia of Maryland
Yes
$
0.9
Incremental costs (including incremental bad debt expense) incurred to ensure that customers have essential utility service during the state of emergency in Maryland. Such incremental costs must be offset by any benefit received in connection with the pandemic
The Pennsylvania PUC adopted an order on March 11, 2021, and subsequently reaffirmed their stance in a June 23, 2021 order, which lifted its prior pandemic-related moratorium on service terminations for non-payments of utility bills beginning April 1, 2021. Pursuant to that order, Pennsylvania utilities are required to offer payment plans on billing arrearages, with the length of such payment plans depending on customers' income levels. The longest such payment plan would be a maximum of five years for residential customers with incomes below 250% of the Federal Poverty Level.
For Columbia of Virginia, the currently effective legislative and regulatory directives related to the COVID-19 pandemic require utilities to offer payment plans between 6 and 24 months, and suspend service disconnections and late payment fees for customers. According to state law, these directives remain in place until the Governor determines that the economic and public health conditions have improved such that the prohibition does not need to be in place, or until at least 60 days after such declared state of emergency ends, whichever is sooner. The state of emergency ended June 30, 2021.
Notes to Condensed Consolidated Financial Statements (unaudited) (continued)
In conjunction with the order issued by the PSC of Maryland on June 15, 2021, all termination moratoriums will be lifted the later of November 1, 2021 or 30 days after the Maryland Relief Act funds have been applied to customer accounts. Columbia of Maryland received approximately $0.8 million of assistance to be applied to customer accounts and is currently in the process of applying these funds to customer accounts in accordance with the terms of the order. Normal collections procedures are expected to resume by November 1, 2021.
9. Risk Management Activities
We are exposed to certain risks relating to our ongoing business operations, namely commodity price risk and interest rate risk. We recognize that the prudent and selective use of derivatives may help to lower our cost of debt capital, manage our interest rate exposure and limit volatility in the price of natural gas.
Risk management assets and liabilities on our derivatives are presented on the Condensed Consolidated Balance Sheets (unaudited) as shown below:
(in millions)
June 30, 2021
December 31, 2020
Risk Management Assets - Current(1)
Interest rate risk programs
$
—
$
—
Commodity price risk programs
7.4
10.4
Total
$
7.4
$
10.4
Risk Management Assets - Noncurrent(2)
Interest rate risk programs
$
—
$
—
Commodity price risk programs
5.0
2.8
Total
$
5.0
$
2.8
Risk Management Liabilities - Current(3)
Interest rate risk programs
$
50.6
$
70.9
Commodity price risk programs
0.8
7.3
Total
$
51.4
$
78.2
Risk Management Liabilities - Noncurrent(4)
Interest rate risk programs
$
73.4
$
99.5
Commodity price risk programs
23.8
45.1
Total
$
97.2
$
144.6
(1)Presented in "Prepayments and other" on the Condensed Consolidated Balance Sheets (unaudited).
(2)Presented in "Deferred charges and other" on the Condensed Consolidated Balance Sheets (unaudited).
(3)Presented in "Other accruals" on the Condensed Consolidated Balance Sheets (unaudited).
(4)Presented in "Other noncurrent liabilities" on the Condensed Consolidated Balance Sheets (unaudited).
Commodity Price Risk Management
We, along with our utility customers, are exposed to variability in cash flows associated with natural gas purchases and volatility in natural gas prices. We purchase natural gas for sale and delivery to our retail, commercial and industrial customers, and for most customers the variability in the market price of gas is passed through in their rates. Some of our utility subsidiaries offer programs to certain customers whereby variability in the market price of gas is assumed by the respective utility. The objective of our commodity price risk programs is to mitigate the gas cost variability, for us or on behalf of our customers, associated with natural gas purchases or sales by economically hedging the various gas cost components using a combination of futures, options, forwards or other derivative contracts.
NIPSCO received IURC approval to lock in a fixed price for its natural gas customers using long-term forward purchase instruments. The term of these instruments may range from five to 10 years and is limited to 20% of NIPSCO’s average annual GCA purchase volume. Gains and losses on these derivative contracts are deferred as regulatory liabilities or assets and are remitted to or collected from customers through NIPSCO’s quarterly GCA mechanism. These instruments are not designated as accounting hedges.
Notes to Condensed Consolidated Financial Statements (unaudited) (continued)
Interest Rate Risk Management
As of June 30, 2021, we have two forward-starting interest rate swaps with an aggregate notional value totaling $500.0 million to hedge the variability in cash flows attributable to changes in the benchmark interest rate during the periods from the effective dates of the swaps to the anticipated dates of forecasted debt issuances, which are expected to take place between 2022 and 2024. These interest rate swaps are designated as cash flow hedges. The gains and losses related to these swaps are recorded to AOCI and will be recognized in "Interest expense, net" concurrently with the recognition of interest expense on the associated debt, once issued. If it becomes probable that a hedged forecasted transaction will no longer occur, the accumulated gains or losses on the derivative will be recognized currently in "Other, net" in the Condensed Statements of Consolidated Income (Loss) (unaudited).
There were no amounts excluded from effectiveness testing for derivatives in cash flow hedging relationships at June 30, 2021 and December 31, 2020.
Our derivative instruments measured at fair value as of June 30, 2021 and December 31, 2020 do not contain any credit-risk-related contingent features.
10. Fair Value
A. Fair Value Measurements
Recurring Fair Value Measurements
The following tables present financial assets and liabilities measured and recorded at fair value on our Condensed Consolidated Balance Sheets (unaudited) on a recurring basis and their level within the fair value hierarchy as of June 30, 2021 and December 31, 2020:
Recurring Fair Value Measurements June 30, 2021 (in millions)
Quoted Prices in Active Markets for Identical Assets (Level 1)
Significant Other Observable Inputs (Level 2)
Significant Unobservable Inputs (Level 3)
Balance as of
June 30, 2021
Assets
Risk management assets
$
—
$
12.4
$
—
$
12.4
Available-for-sale debt securities
—
166.3
—
166.3
Total
$
—
$
178.7
$
—
$
178.7
Liabilities
Risk management liabilities
$
—
$
148.6
$
—
$
148.6
Total
$
—
$
148.6
$
—
$
148.6
Recurring Fair Value Measurements December 31, 2020 (in millions)
Quoted Prices in Active Markets for Identical Assets (Level 1)
Significant Other Observable Inputs (Level 2)
Significant Unobservable Inputs (Level 3)
Balance as of
December 31, 2020
Assets
Risk management assets
$
—
$
13.2
$
—
$
13.2
Available-for-sale debt securities
—
170.9
—
170.9
Total
$
—
$
184.1
$
—
$
184.1
Liabilities
Risk management liabilities
$
—
$
222.8
$
—
$
222.8
Total
$
—
$
222.8
$
—
$
222.8
Risk Management Assets and Liabilities. Risk management assets and liabilities include interest rate swaps, exchange-traded NYMEX futures and NYMEX options and non-exchange-based forward purchase contracts.
Level 1- When utilized, exchange-traded derivative contracts are based on unadjusted quoted prices in active markets and are classified within Level 1. These financial assets and liabilities are secured with cash on deposit with the exchange; therefore,
Notes to Condensed Consolidated Financial Statements (unaudited) (continued)
nonperformance risk has not been incorporated into these valuations. These financial assets and liabilities are deemed to be cleared and settled daily by NYMEX as the related cash collateral is posted with the exchange. As a result of this exchange rule, NYMEX derivatives are considered to have no fair value at the balance sheet date for financial reporting purposes, and are presented in Level 1 net of posted cash; however, the derivatives remain outstanding and are subject to future commodity price fluctuations until they are settled in accordance with their contractual terms.
Level 2- Certain non-exchange-traded derivatives are valued using broker or over-the-counter, on-line exchanges. In such cases, these non-exchange-traded derivatives are classified within Level 2. Non-exchange-based derivative instruments include swaps, forwards, and options. In certain instances, these instruments may utilize models to measure fair value. We use a similar model to value similar instruments. Valuation models utilize various inputs that include quoted prices for similar assets or liabilities in active markets, quoted prices for identical or similar assets or liabilities in markets that are not active, other observable inputs for the asset or liability and market-corroborated inputs, (i.e., inputs derived principally from or corroborated by observable market data by correlation or other means). Where observable inputs are available for substantially the full term of the asset or liability, the instrument is categorized within Level 2.
Level 3- Certain derivatives trade in less active markets with a lower availability of pricing information and models may be utilized in the valuation. When such inputs have a significant impact on the measurement of fair value, the instrument is categorized within Level 3.
Credit risk is considered in the fair value calculation of derivative instruments that are not exchange-traded. Credit exposures are adjusted to reflect collateral agreements which reduce exposures. As of June 30, 2021 and December 31, 2020, there were no material transfers between fair value hierarchies. Additionally, there were no changes in the method or significant assumptions used to estimate the fair value of our financial instruments.
Credit risk is considered in the fair value calculation of each of our forward-starting interest rate swaps, as described in Note 9, "Risk Management Activities." As they are based on observable data and valuations of similar instruments, the hedges are categorized within Level 2 of the fair value hierarchy. There was no exchange of premium at the initial date of the swaps, and we can settle the contracts at any time.
NIPSCO has entered into long-term forward natural gas purchase instruments to lock in a fixed price for its natural gas customers. We value these contracts using a pricing model that incorporates market-based information when available, as these instruments trade less frequently and are classified within Level 2 of the fair value hierarchy. For additional information, see Note 9, “Risk Management Activities.”
Available-for-Sale Debt Securities. Available-for-sale debt securities are investments pledged as collateral for trust accounts related to our wholly owned insurance company. We value U.S. Treasury, corporate debt and mortgage-backed securities using a matrix pricing model that incorporates market-based information. These securities trade less frequently and are classified within Level 2.
At each reporting date, we quantitatively and qualitatively assess available-for-sale debt securities for impairment. For securities in a loss position that we intend to hold, we perform an analysis to determine whether the unrealized loss is related to credit factors. The analysis focuses on a variety of factors that include, but are not limited to, downgrade on ratings of the security, defaults in the current reporting period or projected defaults in the future, the security's yield spread over treasuries, and other relevant market data. If the unrealized loss is not related to credit factors, it is included in other comprehensive income. If the unrealized loss is related to credit factors, the loss is recognized as credit loss expense in earnings during the period, with an offsetting entry to the allowance for credit losses. The amount of the credit loss recorded to the allowance account is limited by the amount at which the security's fair value is less than its amortized cost basis. If the credit losses in the allowance for credit losses are deemed uncollectible, the allowance on the uncollectible portion is charged off, with an offsetting entry to the carrying value of the security. Subsequent improvements to the estimated credit losses of available-for-sale debt securities are recognized immediately in earnings. As of June 30, 2021 and December 31, 2020, we recorded $0.2 million and $0.5 million, respectively, as an allowance for credit losses on available-for-sale debt securities as a result of the analysis described above. Continuous credit monitoring and portfolio credit balancing mitigates our risk of credit losses on our available-for-sale debt securities.
Notes to Condensed Consolidated Financial Statements (unaudited) (continued)
The amortized cost, gross unrealized gains and losses, allowance for credit losses, and fair value of available-for-sale securities at June 30, 2021 and December 31, 2020 were:
June 30, 2021 (in millions)
Amortized Cost
Gross Unrealized Gains
Gross Unrealized Losses(1)
Allowance for Credit Losses
Fair Value
Available-for-sale debt securities
U.S. Treasury debt securities
$
37.4
$
0.2
$
(0.1)
$
—
$
37.5
Corporate/Other debt securities
123.6
5.8
(0.4)
(0.2)
128.8
Total
$
161.0
$
6.0
$
(0.5)
$
(0.2)
$
166.3
December 31, 2020 (in millions)
Amortized Cost
Gross Unrealized Gains
Gross Unrealized Losses(2)
Allowance for Credit Losses
Fair Value
Available-for-sale debt securities
U.S. Treasury debt securities
$
33.7
$
0.3
$
—
$
—
$
34.0
Corporate/Other debt securities
130.2
7.7
(0.5)
(0.5)
136.9
Total
$
163.9
$
8.0
$
(0.5)
$
(0.5)
$
170.9
(1)Fair value of U.S. Treasury debt securities and Corporate/Other debt securities in an unrealized loss position without an allowance for credit losses is $25.1 million and $23.5 million, respectively, at June 30, 2021.
(2)Fair value of U.S. Treasury debt securities and Corporate/Other debt securities in an unrealized loss position without an allowance for credit losses is $0 million and $13.2 million, respectively, at December 31, 2020.
Realized gains and losses on available-for-sale securities were immaterial for the three and six months ended June 30, 2021 and 2020.
The cost of maturities sold is based upon specific identification. At June 30, 2021, approximately $11.4 million of U.S. Treasury debt securities and approximately $3.4 million of Corporate/Other debt securities have maturities of less than a year.
There are no material items in the fair value reconciliation of Level 3 assets and liabilities measured at fair value on a recurring basis as of June 30, 2021 and December 31, 2020.
Non-recurring Fair Value Measurements
We measure the fair value of certain assets, including goodwill, on a non-recurring basis, typically annually or when events or changes in circumstances indicate that the carrying amount of the assets may not be recoverable.
In March 2021, we reached an agreement with Eversource regarding the final purchase price, including net working capital adjustments to the October 9, 2020 purchase price of our Massachusetts Business. The working capital amounts were measured at fair value, less costs to sell.
B. Other Fair Value Disclosures for Financial Instruments. The carrying amount of cash and cash equivalents, restricted cash, customer deposits and short-term borrowings is a reasonable estimate of fair value due to their liquid or short-term nature.
The following method and assumptions were used to estimate the fair value of each class of financial instruments.
Purchase Contract Liability. At April 19, 2021, we recorded the purchase contract liability at fair value using a discounted cash flow method and observable, market-corroborated inputs. This value is a reasonable estimate of fair value at June 30, 2021, and has been categorized within Level 2 of the fair value hierarchy. Refer to Note 5, “Equity,” for additional information.
Long-term Debt. Our long-term borrowings are recorded at historical amounts. The fair value of outstanding long-term debt is estimated based on the quoted market prices for the same or similar securities. Certain premium costs associated with the early settlement of long-term debt are not taken into consideration in determining fair value. These fair value measurements are classified within Level 2 of the fair value hierarchy. As of June 30, 2021, there was no change in the method or significant assumptions used to estimate the fair value of long-term debt.
Notes to Condensed Consolidated Financial Statements (unaudited) (continued)
The carrying amount and estimated fair values of these financial instruments were as follows:
(in millions)
Carrying
Amount as of
June 30, 2021
Estimated Fair
Value as of
June 30, 2021
Carrying Amount as of Dec. 31, 2020
Estimated Fair Value as of Dec. 31, 2020
Long-term debt (including current portion)
$
9,246.9
$
10,577.4
$
9,243.1
$
11,034.2
11.Goodwill
The following presents our goodwill balance allocated by segment as of June 30, 2021:
(in millions)
Gas Distribution Operations
Electric Operations
Corporate and Other
Total
Goodwill
$
1,485.9
$
—
$
—
$
1,485.9
For our annual goodwill impairment analysis performed as of May 1, 2021, we performed a qualitative "step 0" assessment and determined that it was more likely than not that the estimated fair value of the reporting unit substantially exceeded the related carrying value of our reporting unit. For this test, we assessed various assumptions, events and circumstances that would have affected the estimated fair value of the reporting units as compared to their baseline May 1, 2020 "step 1" fair value measurement. There have been no impairments to the carrying value of our goodwill during the periods presented.
12. Income Taxes
Our interim effective tax rates reflect the estimated annual effective tax rates for 2021 and 2020, adjusted for tax expense associated with certain discrete items. The effective tax rates for the three months ended June 30, 2021 and 2020 were 18.8% and 491.7%, respectively. The effective tax rates for the six months ended June 30, 2021 and 2020 were 17.7% and (14.5)%, respectively. These effective tax rates differ from the federal statutory tax rate of 21% primarily due to increased amortization of excess deferred federal income tax liabilities, as specified in the TCJA, tax credits, state income taxes and other permanent book-to-tax differences. These adjustments have a relative impact on the effective tax rate proportionally to pretax income or loss.
The decrease in the three month effective tax rate of 472.9% in 2021 compared to 2020 is primarily attributable to a discrete item related to the pre-tax book loss recorded for the classification as held for sale of the Massachusetts Business tax effected at statutory tax rates in 2020.
The increase in the six month effective tax rate of 32.2% in 2021 compared to 2020 is primarily attributed to a discrete item related to the pre-tax book loss recorded for the classification as held for sale of the Massachusetts Business tax effected at statutory tax rates in 2020.
There were no material changes recorded in 2021 to our uncertain tax positions recorded as of December 31, 2020.
13. Pension and Other Postretirement Benefits
We provide defined contribution plans and noncontributory defined benefit retirement plans that cover certain of our employees. Benefits under the defined benefit retirement plans reflect the employees’ compensation, years of service and age at retirement. Additionally, we provide health care and life insurance benefits for certain retired employees. The majority of employees may become eligible for these benefits if they reach retirement age while working for us. The expected cost of such benefits is accrued during the employees’ years of service. We determined that, for certain rate-regulated subsidiaries, the future recovery of postretirement benefit costs is probable, and we record regulatory assets and liabilities for amounts that would otherwise have been recorded to expense or accumulated other comprehensive loss. Current rates of rate-regulated companies include postretirement benefit costs, including amortization of the regulatory assets and liabilities that arose prior to inclusion of these costs in rates. For most plans, cash contributions are remitted to grantor trusts.
For the six months ended June 30, 2021, we contributed $2.0 million to our pension plans and $10.2 million to our other postretirement benefit plans.
Notes to Condensed Consolidated Financial Statements (unaudited) (continued)
The following table provides the components of the plans’ actuarially determined net periodic benefit cost for the three and six months ended June 30, 2021 and 2020:
Pension Benefits
Other Postretirement Benefits
Three Months Ended June 30, (in millions)
2021
2020
2021
2020
Components of Net Periodic Benefit (Income) Cost(1)
Service cost
$
7.5
$
8.0
$
1.5
$
1.6
Interest cost
7.9
13.5
2.5
3.9
Expected return on assets
(25.3)
(28.4)
(3.8)
(3.6)
Amortization of prior service credit
—
0.2
(0.6)
(0.5)
Recognized actuarial loss
5.5
8.7
1.2
1.3
Settlement loss
3.3
—
—
—
Total Net Periodic Benefit (Income) Cost
$
(1.1)
$
2.0
$
0.8
$
2.7
(1)The service cost component and all non-service cost components of net periodic benefit (income) cost are presented in "Operation and maintenance" and "Other, net," respectively, on the Condensed Statements of Consolidated Income (Loss) (unaudited).
Pension Benefits
Other Postretirement Benefits
Six Months Ended June 30, (in millions)
2021
2020
2021
2020
Components of Net Periodic Benefit (Income) Cost(1)
Service cost
$
15.1
$
16.0
$
3.0
$
3.2
Interest cost
15.6
27.0
5.0
7.8
Expected return on assets
(51.1)
(56.8)
(7.6)
(7.2)
Amortization of prior service credit
—
0.4
(1.2)
(1.0)
Recognized actuarial loss
10.8
17.4
2.4
2.6
Settlement loss
6.6
—
—
—
Total Net Periodic Benefit (Income) Cost
$
(3.0)
$
4.0
$
1.6
$
5.4
(1)The service cost component and all non-service cost components of net periodic benefit cost (income) are presented in "Operation and maintenance" and "Other, net," respectively, on the Condensed Statements of Consolidated Income (Loss) (unaudited).
During the first quarter of 2021, one of our qualified pension plans met the requirement for settlement accounting. A settlement charge of $3.3 million was recorded during the first quarter of 2021. As a result of the settlement, the pension plan was remeasured, resulting in a decrease to the net pension asset of $5.8 million, a net increase to regulatory assets of $2.1 million, and a net debit to accumulated other comprehensive loss of $0.4 million. Net periodic pension benefit cost for 2021 increased by $4.0 million as a result of the interim remeasurement.
During the second quarter of 2021, the requirements for settlement accounting were also met, resulting in a settlement charge of $3.3 million recorded for the three months ended June 30, 2021.
The following table provides the key assumptions that were used to calculate the pension benefit obligation and the net periodic benefit cost at the interim remeasurement date for the plan that triggered settlement accounting:
February 28, 2021
Weighted-average Assumption to Determine Benefit Obligation
Discount rate
2.57
%
Weighted-average Assumptions to Determine Net Periodic Benefit Costs for the period ended
Notes to Condensed Consolidated Financial Statements (unaudited) (continued)
14. Variable Interest Entities
A VIE is an entity in which the controlling interest is determined through means other than a majority voting interest. The primary beneficiary of a VIE is the business enterprise which has the power to direct the activities that most significantly impact the VIE’s economic performance. Also, the primary beneficiary either absorbs a significant amount of the VIE’s losses or has the right to receive benefits that could be significant to the VIE. We consider these qualitative elements in determining whether we are the primary beneficiary of a VIE, and we consolidate those VIEs for which we are determined to be the primary beneficiary.
Rosewater (a joint venture) owns and operates 102 MW of nameplate capacity wind generation assets. Members of the joint venture are NIPSCO (who is the managing member) and a tax equity partner. Earnings, tax attributes and cash flows are allocated to both NIPSCO and the tax equity partner in varying percentages by category and over the life of the partnership. Once the tax equity partner has earned their negotiated rate of return and we have reached the agreed upon contractual date, NIPSCO has the option to purchase at fair market value from the tax equity partner the remaining interest in the aforementioned joint venture. NIPSCO has an obligation to purchase, through a PPA at established market rates, 100% of the electricity generated by Rosewater.
As the managing member of Rosewater, we control decisions that are significant to its ongoing operations and economic results. Therefore, we have concluded that we are the primary beneficiary of Rosewater and have consolidated Rosewater even though we own less than 100% of the total equity membership interest.
We have applied the HLBV method of attributing income and loss to the noncontrolling interest held by the tax equity partner. HLBV accounting was applied as the allocation of Rosewater's economic results to members differs from the members' relative ownership percentages. Using the HLBV method, our earnings are calculated based on how the partnership would distribute its cash if it were to hypothetically sell all of its assets for their carrying amounts and liquidate at each reporting period. Under HLBV, we calculate the liquidation value allocable to each partner at the beginning and end of each period based on the contractual terms of the related entity's operating agreement and adjust our income for the period to reflect the change in our associated book value.
In March 2021, in exchange for additional respective membership interests in Rosewater, NIPSCO contributed $0.1 million in cash, and the tax equity partner contributed $7.5 million in cash, the second of two contractual cash contributions for each partner, per the equity capital contribution agreement. NIPSCO also assumed an additional obligation of $6.0 million to the developer, which comes due in 2023 and is included in "Other noncurrent liabilities" in the Condensed Consolidated Balance Sheets (unaudited). From the contributed funds, Rosewater paid $7.4 million to the developer of the wind generation assets. The developer of the facility is not a partner in the joint venture for federal income tax purposes and does not receive any share of earnings, tax attributes, or cash flows of Rosewater. With asset construction now complete, NIPSCO and the tax equity partner have made total cash contributions of $0.8 million and $93.6 million, respectively, and NIPSCO has assumed an obligation to the developer of $75.7 million, totaling contributions of $170.1 million for both partners. We did not provide any financial or other support during the year that was not previously contractually required, nor do we expect to provide such support in the future.
At June 30, 2021 and December 31, 2020, $169.2 million and $156.4 million, respectively, in net assets (as detailed in the table below) related to Rosewater and the non-controlling interest attributable to the unrelated tax equity partner of $90.4 million and $85.6 million, respectively, were included in the Condensed Consolidated Balance Sheets (unaudited). Amounts allocated to the tax equity partner were $3.4 million and zero for the three months ended June 30, 2021 and 2020, respectively, and $2.4 million and zero for the six months ended June 30, 2021 and 2020, respectively. These amounts are included in "Net loss attributable to non-controlling interest" on the Condensed Statements of Consolidated Income (Loss) (unaudited).
Notes to Condensed Consolidated Financial Statements (unaudited) (continued)
Our Condensed Consolidated Balance Sheets (unaudited) included the following assets and liabilities associated with Rosewater:
(in millions)
June 30, 2021
December 31, 2020
Net Property, Plant and Equipment
$
172.8
$
175.6
Current assets
4.8
1.7
Total assets(1)
$
177.6
$
177.3
Current liabilities
$
2.7
$
15.3
Asset retirement obligations
5.6
5.5
Other noncurrent liabilities
0.1
0.1
Total liabilities
$
8.4
$
20.9
(1)The assets of Rosewater represent assets of a consolidated VIE that can be used only to settle obligations of the consolidated VIE.
15. Short-Term Borrowings
We generate short-term borrowings through several sources, described in further detail below.
Revolving Credit Facility. We maintain a revolving credit facility to fund ongoing working capital requirements, including the provision of liquidity support for our commercial paper program, provide for issuance of letters of credit and also for general corporate purposes. Our revolving credit facility has a program limit of $1.85 billion and is comprised of a syndicate of banks led by Barclays. We had no outstanding borrowings under this facility as of June 30, 2021 and December 31, 2020.
Commercial Paper Program. Our commercial paper program has a program limit of up to $1.5 billion with a dealer group comprised of Barclays, Citigroup, Credit Suisse and Wells Fargo. We had no commercial paper outstanding as of June 30, 2021 and $503.0 million of commercial paper outstanding as of December 31, 2020.
Accounts Receivable Transfer Programs. Columbia of Ohio, NIPSCO and Columbia of Pennsylvania each maintain a receivables agreement whereby they may transfer their customer accounts receivables to third-party financial institutions through wholly owned and consolidated special purpose entities. The three agreements expire between August 2021 and May 2022 and may be further extended if mutually agreed to by the parties thereto.
All receivables transferred to third parties are valued at face value, which approximates fair value due to their short-term nature. The amount of the undivided percentage ownership interest in the accounts receivables transferred is determined in part by required loss reserves under the agreements.
Transfers of accounts receivable are accounted for as secured borrowings resulting in the recognition of short-term borrowings on the Condensed Consolidated Balance Sheets (unaudited). As of June 30, 2021, the maximum amount of debt that could be recognized related to our accounts receivable programs is $340.0 million.
We had no short-term borrowings related to the securitization transactions as of June 30, 2021 and December 31, 2020.
For the six months ended June 30, 2021 and 2020, zero and $39.7 million, respectively, were recorded as cash flows used for financing activities related to the change in short-term borrowings due to securitization transactions. For the accounts receivable transfer programs, we pay used facility fees for amounts borrowed, unused commitment fees for amounts not borrowed, and upfront renewal fees. Fees associated with the securitization transactions were $0.4 million and $0.8 million for the three months ended June 30, 2021 and 2020, respectively, and $0.8 million and $1.5 million for the six months ended June 30, 2021 and 2020, respectively. Columbia of Ohio, NIPSCO and Columbia of Pennsylvania remain responsible for collecting on the receivables securitized, and the receivables cannot be transferred to another party.
Notes to Condensed Consolidated Financial Statements (unaudited) (continued)
Total short-term borrowings were as follows:
(in millions)
June 30, 2021
December 31, 2020
Commercial paper weighted-average interest rate of 0.27% at December 31, 2020
—
503.0
Total short-term borrowings
$
—
$
503.0
Items listed above are presented net in the Condensed Statements of Consolidated Cash Flows (unaudited) as their maturities are less than 90 days.
16. Other Commitments and Contingencies
A. Guarantees and Indemnities. We and certain of our subsidiaries enter into various agreements providing financial or performance assurance to third parties on behalf of certain subsidiaries as a part of normal business. Such agreements include guarantees and stand-by letters of credit. These agreements are entered into primarily to support or enhance the creditworthiness otherwise attributed to a subsidiary on a stand-alone basis, thereby facilitating the extension of sufficient credit to accomplish the subsidiaries’ intended commercial purposes. As of June 30, 2021 and December 31, 2020, we had issued stand-by letters of credit of $14.1 million and $15.2 million, respectively.
We provide guarantees related to our future performance under BTAs for our renewable generation projects. At June 30, 2021, our guarantees for the Rosewater and Indiana Crossroads BTAs totaled $519.5 million. In July 2021, the amount of the guarantees increased to $544.7 million in accordance with the Dunn's Bridge I BTA. The amount of each guaranty will fluctuate upon the completion of the various steps outlined in each BTA. See “- E. Other Matters - Generation Transition,” below for more information.
B. Legal Proceedings. On September 13, 2018, a series of fires and explosions occurred in Lawrence, Andover and North Andover, Massachusetts related to the delivery of natural gas by Columbia of Massachusetts (the "Greater Lawrence Incident"). The Greater Lawrence Incident resulted in one fatality and a number of injuries, damaged multiple homes and businesses, and caused the temporary evacuation of significant portions of each municipality. The Massachusetts Governor’s Office declared a state of emergency, authorizing the Massachusetts DPU to order another utility company to coordinate the restoration of utility services in Lawrence, Andover and North Andover. The incident resulted in the interruption of gas for approximately 7,500 gas meters, the majority of which served residences and approximately 700 of which served businesses, and the interruption of other utility service more broadly in the area. Columbia of Massachusetts replaced the cast iron and bare steel gas pipeline system in the affected area and restored service. See “- C. Other Greater Lawrence Incident Matters below for more information. On September 1, 2020, the Massachusetts Governor terminated the state of emergency declared following the Greater Lawrence Incident.
We have been subject to inquiries and investigations by government authorities and regulatory agencies regarding the Greater Lawrence Incident. On February 26, 2020, the Company and Columbia of Massachusetts entered into agreements with the U.S. Attorney’s Office for the District of Massachusetts to resolve the U.S. Attorney’s Office’s investigation relating to the Greater Lawrence Incident, as described below. The Company and Columbia of Massachusetts entered into an agreement with the Massachusetts Attorney General’s Office (among other parties) to resolve the Massachusetts DPU and the Massachusetts Attorney General’s Office investigations, that was approved by the Massachusetts DPU on October 7, 2020 as part of the sale of the Massachusetts Business to Eversource.
U.S. Department of Justice Investigation. On February 26, 2020, the Company and Columbia of Massachusetts entered into agreements with the U.S. Attorney’s Office to resolve the U.S. Attorney’s Office’s investigation relating to the Greater Lawrence Incident. Columbia of Massachusetts agreed to plead guilty in the United States District Court for the District of Massachusetts (the “Court”) to violating the Natural Gas Pipeline Safety Act (the “Plea Agreement”), and the Company entered into a Deferred Prosecution Agreement (the “DPA”).
Notes to Condensed Consolidated Financial Statements (unaudited) (continued)
On March 9, 2020, Columbia of Massachusetts entered its guilty plea pursuant to the Plea Agreement, which the Court accepted. Subsequently, Columbia of Massachusetts and the U.S. Attorney’s Office modified the Plea Agreement. On June 23, 2020, the Court sentenced Columbia of Massachusetts in accordance with the terms of the modified Plea Agreement.Under the modified Plea Agreement, Columbia of Massachusetts is subject to the following terms, among others: (i) a criminal fine in the amount of $53,030,116; (ii) a three-year probationary period that will terminate early upon a sale of Columbia of Massachusetts or a sale of its gas distribution business to a qualified third-party buyer consistent with certain requirements, but in no event before the end of the one-year mandatory period of probation; (iii) compliance with each of the NTSB recommendations stemming from the Greater Lawrence Incident; and (iv) employment of an in-house monitor until the end of the term of probation or until the sale of Columbia of Massachusetts or its gas distribution business, whichever is earlier. On June 23, 2021, the Court accepted a joint request by Columbia Gas of Massachusetts and the U.S. Attorney's Office to terminate the three-year probation effective immediately, which was at the end of the one-year minimum probationary period, marking the completion of all terms of the modified plea agreement.
Under the DPA, the U.S. Attorney’s Office agreed to defer prosecution of the Company in connection with the Greater Lawrence Incident for a three-year period (which three-year period may be extended for twelve (12) months upon the U.S. Attorney’s Office’s determination of a breach of the DPA) subject to certain obligations of the Company, including, but not limited to, the following: (i) the Company will use reasonable best efforts to sell Columbia of Massachusetts or Columbia of Massachusetts’ gas distribution business to a qualified third-party buyer consistent with certain requirements, and, upon the completion of any such sale, the Company will cease and desist any and all gas pipeline and distribution activities in the District of Massachusetts; (ii) the Company will forfeit and pay, within 30 days of the later of the sale becoming final or the date on which post-closing adjustments to the purchase price are finally determined in accordance with the agreement to sell Columbia of Massachusetts or its gas distribution business, a fine equal to the total amount of the profit or gain, if any, from any sale of Columbia of Massachusetts or its gas distribution business, with the amount of profit or gain determined as provided in the DPA; and (iii) the Company agrees as to each of the Company’s subsidiaries involved in the distribution of gas through pipeline facilities in Massachusetts, Indiana, Ohio, Pennsylvania, Maryland, Kentucky and Virginia to implement and adhere to each of the recommendations from the NTSB stemming from the Greater Lawrence Incident. Pursuant to the DPA, if the Company complies with all of its obligations under the DPA, including, but not limited to those identified above, the U.S. Attorney’s Office will not file any criminal charges against the Company related to the Greater Lawrence Incident. If Columbia of Massachusetts withdraws its plea for any reason, if the Court rejects any aspect of the Plea Agreement, or if Columbia of Massachusetts should fail to perform an obligation under the Plea Agreement prior to the sale of Columbia of Massachusetts or its gas distribution business, the U.S. Attorney's Office may, at its sole option, render the DPA null and void. The sale of the Massachusetts Business was completed on October 9, 2020. The Company was not required to forfeit or pay any funds because the Company did not realize a profit or gain from the sale as provided in the DPA.
Private Actions. Various lawsuits, including several purported class action lawsuits, have been filed by various affected residents or businesses in Massachusetts state courts against the Company and/or Columbia of Massachusetts in connection with the Greater Lawrence Incident.
On July 26, 2019, the Company, Columbia of Massachusetts and NiSource Corporate Services Company, a subsidiary of the Company, entered into a term sheet with the class action plaintiffs under which they agreed to settle the class action claims in connection with the Greater Lawrence Incident. Columbia of Massachusetts agreed to pay $143 million into a settlement fund to compensate the settlement class and the settlement class agreed to release Columbia of Massachusetts and affiliates from all claims arising out of or related to the Greater Lawrence Incident. The following claims are not covered under the proposed settlement because they are not part of the consolidated class action: (1) physical bodily injury and wrongful death; (2) insurance subrogation, whether equitable, contractual or otherwise; and (3) claims arising out of appliances that are subject to the Massachusetts DPU orders. Emotional distress and similar claims are covered under the proposed settlement unless they are secondary to a physical bodily injury. The settlement class is defined under the term sheet as all persons and businesses in the three municipalities of Lawrence, Andover and North Andover, Massachusetts, subject to certain limited exceptions. The motion for preliminary approval and the settlement documents were filed on September 25, 2019. The preliminary approval court hearing was held on October 7, 2019 and the court issued an order granting preliminary approval of the settlement on October 11, 2019. The Court granted final approval of the settlement on March 12, 2020.
With respect to claims not included in the consolidated class action, many of the asserted wrongful death and bodily injury claims have settled, and we continue to discuss potential settlements with remaining claimants. The outcomes and impacts of such private actions are uncertain at this time.
Notes to Condensed Consolidated Financial Statements (unaudited) (continued)
Shareholder Derivative Lawsuit. On April 28, 2020, a shareholder derivative lawsuit was filed by the City of Detroit Police and Fire Retirement System in the United States District Court for the District of Delaware against certain of the Company’s current and former directors, alleging state-law claims for breaches of fiduciary duty with respect to the pipeline safety management systems relating to the distribution of natural gas prior to the Greater Lawrence Incident and also including federal-law claims related to our proxy statement disclosures regarding our safety systems. The remedies sought included damages for the alleged breaches of fiduciary duty, corporate governance reforms, and restitution of any unjust enrichment. The defendants filed a motion to dismiss the lawsuit, and oral argument was held on March 2, 2021. On March 9, 2021, the district court granted the defendants’ motion to dismiss. It dismissed the federal-law claims with prejudice for failure to state a claim on which relief can be granted and declined to exercise jurisdiction over the state-law claims, which were dismissed without prejudice.
Following the dismissal of the federal court action, on April 29, 2021, the same plaintiff filed a shareholder derivative lawsuit in the Delaware Court of Chancery against certain of our current and former directors. The new complaint alleges a single count for breach of fiduciary duty, and no longer alleges disclosure violations or breaches of federal securities laws. The complaint relates to substantially the same matters as those alleged in the dismissed federal derivative complaint. The remedies sought include damages for the alleged breaches of fiduciary duty, corporate governance reforms, and restitution of compensation by the individual defendants. On May 19, 2021, the defendants filed a motion to dismiss the lawsuit, and on July 2, 2021, they filed their brief in support of the motion. The plaintiff's opposition to the motion is due on August 26, 2021, and the defendants' reply brief is due on September 24, 2021. Because of the preliminary nature of this lawsuit, we are not able to estimate a loss or range of loss, if any, that may be incurred in connection with this matter at this time.
Remaining Claims. Due to the inherent uncertainty of litigation, there can be no assurance that the outcome or resolution of any particular claim, proceeding or investigation related to the Greater Lawrence Incident or otherwise would not have a material adverse effect on our results of operations, financial position or liquidity. Certain matters in connection with the Greater Lawrence Incident have had or may have a material impact as described above. If one or more of such additional or other matters were decided against us, the effects could 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 also party to certain other claims, regulatory and legal proceedings arising in the ordinary course of business in each state in which we have operations, none of which we believe to be individually material at this time.
C. Other Greater Lawrence Incident Matters. In connection with the Greater Lawrence Incident, Columbia of Massachusetts, in cooperation with the Massachusetts Governor’s office, replaced the entire affected pipeline system. We invested approximately $258 million of capital spend for the pipeline replacement; this work was completed in 2019. We maintain property insurance for gas pipelines and other applicable property. Columbia of Massachusetts has filed a proof of loss with its property insurer for the pipeline replacement. In January 2020, we filed a lawsuit against the property insurer, seeking payment of our property claim. We are currently unable to predict the timing or amount of any insurance recovery under the property policy.
D. Environmental Matters. Our operations are subject to environmental statutes and regulations related to air quality, water quality, hazardous waste and solid waste. We believe that we are in substantial compliance with the environmental regulations currently applicable to our operations.
It is management's continued intent to address environmental issues in cooperation with regulatory authorities in such a manner as to achieve mutually acceptable compliance plans. However, there can be no assurance that fines and penalties will not be incurred. Management expects a majority of environmental assessment and remediation costs to be recoverable through rates for certain of our companies.
As of June 30, 2021 and December 31, 2020, we had recorded a liability of $93.3 million and $92.6 million, respectively, to cover environmental remediation at various sites. The current portion of this liability is included in "Other accruals" in the Condensed Consolidated Balance Sheets (unaudited). The noncurrent portion is included in "Other noncurrent liabilities." We recognize costs associated with environmental remediation obligations when the incurrence of such costs is probable and the amounts can be reasonably estimated. The original estimates for remediation activities may differ materially from the amount ultimately expended. The actual future expenditures depend on many factors, including laws and regulations, the nature and extent of impact and the method of remediation. These expenditures are not currently estimable at some sites. We periodically adjust our liability as information is collected and estimates become more refined.
Notes to Condensed Consolidated Financial Statements (unaudited) (continued)
CERCLA. Our subsidiaries are potentially responsible parties at waste disposal sites under the CERCLA (commonly known as Superfund) and similar state laws. Under CERCLA, each potentially responsible party can be held jointly, severally and strictly liable for the remediation costs as the EPA, or state, can allow the parties to pay for remedial action or perform remedial action themselves and request reimbursement from the potentially responsible parties. Our affiliates have retained CERCLA environmental liabilities, including remediation liabilities, associated with certain current and former operations. These liabilities are not material to the Condensed Consolidated Financial Statements (unaudited).
MGP. We maintain a program to identify and investigate former MGP sites where Gas Distribution Operations subsidiaries or predecessors may have liability. The program has identified 54 such sites where liability is probable. Remedial actions at many of these sites are being overseen by state or federal environmental agencies through consent agreements or voluntary remediation agreements.
We utilize a probabilistic model to estimate our future remediation costs related to MGP sites. The model was prepared with the assistance of a third party and incorporates our experience and general industry experience with remediating MGP sites. We complete an annual refresh of the model in the second quarter of each fiscal year. No material changes to the estimated future remediation costs were noted as a result of the refresh completed as of June 30, 2021. Our total estimated liability related to the facilities subject to remediation was $87.1 million and $85.0 million at June 30, 2021 and December 31, 2020, respectively. The liability represents our best estimate of the probable cost to remediate the MGP sites. We believe that it is reasonably possible that remediation costs could vary by as much as $17 million in addition to the costs noted above. Remediation costs are estimated based on the best available information, applicable remediation standards at the balance sheet date and experience with similar facilities.
CCRs. On April 17, 2015, the EPA issued a final rule for regulation of CCRs. The rule regulates CCRs under the RCRA Subtitle D, which determines them to be nonhazardous. The rule is implemented in phases and requires increased groundwater monitoring, reporting, recordkeeping and posting of related information to the Internet. The rule also establishes requirements related to CCR management and disposal. The rule allows NIPSCO to continue its byproduct beneficial use program.
To comply with the rule, NIPSCO completed capital expenditures in 2019 to modify its infrastructure and manage CCRs. The CCR rule also resulted in revisions to previously recorded legal obligations associated with the retirement of certain NIPSCO facilities. The actual asset retirement costs related to the CCR rule may vary substantially from the estimates used to record the increased asset retirement obligation due to the uncertainty about the requirements that will be established by environmental authorities, compliance strategies that will be used and the preliminary nature of available data used to estimate costs. As allowed by the rule, NIPSCO will continue to collect data over time to determine the specific compliance solutions and associated costs and, as a result, the actual costs may vary. NIPSCO will also continue to work with EPA and the Indiana Department of Environmental Management to obtain administrative approvals associated with the CCR rule. In the event that the approvals are not obtained, future operations could be impacted. We believe the possibility of such an outcome is remote.
E. Other Matters.
Generation Transition.NIPSCO has executed several PPAs to purchase 100% of the output from renewable generation facilities at a fixed price per MWh. Each facility supplying the energy will have an associated nameplate capacity, and payments under the PPAs will not begin until the associated generation facility is constructed by the owner/seller. NIPSCO has also executed several BTAs with developers to construct renewable generation facilities. NIPSCO's purchase obligation under each respective BTA is dependent on satisfactory approval of the BTA by the IURC, successful execution by NIPSCO of an agreement with a tax equity partner and timely completion of construction. NIPSCO has received IURC approval for all of its BTAs and all but one PPA, which is pending a decision from the IURC. NIPSCO and the tax equity partner are obligated to make cash contributions to the joint venture that acquires the project at the date construction is substantially complete. Once the tax equity partner has earned its negotiated rate of return and we have reached the agreed upon contractual date, NIPSCO has the option to purchase at fair market value from the tax equity partner the remaining interest in the joint venture.
One-Time Employee Separation Benefits. Starting in the third quarter of 2020, we evaluated and continue to evaluate our organizational structure under the auspices of NiSource Next. We recognized the majority of the related severance expense in 2020 when employees accepted severance offers, absent a retention period. In addition, we continue to have separations under our existing severance policies. For employees that have a retention period, expense will be recognized over the remaining service period. The total estimated severance expense for employees is approximately $41 million, with substantially all of it incurred to date. A rollforward of the one-time employee separation benefits accrual for the six months ended June 30, 2021 is presented below:
Notes to Condensed Consolidated Financial Statements (unaudited) (continued)
18. Other, Net
Three Months Ended June 30,
Six Months Ended June 30,
(in millions)
2021
2020
2021
2020
Interest income
$
0.7
$
1.4
$
1.6
$
3.1
AFUDC equity
3.4
1.4
4.9
3.1
Pension and other postretirement non-service benefit
8.6
3.1
17.1
5.8
Miscellaneous
(0.3)
0.6
(0.7)
(0.1)
Total Other, net
$
12.4
$
6.5
$
22.9
$
11.9
19. Business Segment Information
At June 30, 2021, our operations are divided into two primary reportable segments, the Gas Distribution Operations and Electric Operations segments. Corporate costs and other activities that are not significant on a stand-alone basis to warrant treatment as an operating segment and that do not fit into one of our two segments are aggregated as "Corporate and Other" in the disclosures below. Refer to Note 3, "Revenue Recognition," for additional information on our segments and their sources of revenues.
The following table provides information about our business segments. We use operating income as our primary measurement for each of the reported segments and make decisions on finance, dividends and taxes at the corporate level on a consolidated basis. Segment revenues include intersegment sales to affiliated subsidiaries, which are eliminated in consolidation. Affiliated sales are recognized on the basis of prevailing market, regulated prices or at levels provided for under contractual agreements. Operating income is derived from revenues and expenses directly associated with each segment.
ITEM 2.MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (continued)
NiSource Inc.
EXECUTIVE SUMMARY
This Management’s Discussion and Analysis of Financial Condition and Results of Operations ("Management’s Discussion") includes management’s analysis of past financial results and certain potential factors that may affect future results, potential future risks and approaches that may be used to manage those risks. See "Note regarding forward-looking statements" at the beginning of this report for a list of factors that may cause results to differ materially.
Management’s Discussion is designed to provide an understanding of our operations and financial performance and should be read in conjunction with our Annual Report on Form 10-K for the fiscal year ended December 31, 2020.
We are an energy holding company under the Public Utility Holding Company Act of 2005 whose utility subsidiaries are fully regulated natural gas and electric utility companies serving customers in six states. We generate substantially all of our operating income through these rate-regulated businesses, which are summarized for financial reporting purposes into two primary reportable segments: Gas Distribution Operations and Electric Operations.
Refer to the “Business” section of our Annual Report on Form 10-K for the fiscal year ended December 31, 2020 for further discussion of our regulated utility business segments.
Our goal is to develop strategies that benefit all stakeholders as we (i) address changing customer conservation patterns, (ii) align our price structure with our cost structure, and (iii) embark on long-term infrastructure investment and safety programs to better serve our customers. These strategies focus on improving safety and reliability, enhancing customer service, lowering customer bills and reducing emissions while generating sustainable returns. The safety of our customers, communities and employees remains our top priority. The SMS is an established operating model within NiSource. With the continued support and advice from our Quality Review Board (a panel of third parties with safety operations expertise engaged by management to advise on safety matters), we are continuing to mature our SMS processes, capabilities and talent as we collaborate within and across industries to enhance safety and reduce operational risk. Additionally, we continue to pursue regulatory and legislative initiatives that will allow residential customers not currently on our system to obtain gas service in a cost effective manner.
Your Energy, Your Future: Our plan to replace all of our coal generation capacity by the end of 2028 with primarily renewable resources is well underway. As of June 30, 2021, we have executed BTAs and PPAs with a combined nameplate capacity of 1,950 MW and 1,380 MW, respectively, under the plan. We have received IURC approval for all the BTAs and all but one PPA, which is pending a decision from the IURC in the second half of 2021. NIPSCO will refresh its 2018 Integrated Resource Plan in 2021. The 2021 Integrated Resource Plan development is currently underway, and in the second quarter of 2021, we launched an RFP solicitation as part of the IRP's evaluation of resources to meet the future electric needs of our customers. For additional information, see "Results and Discussion of Segment Operation - Electric Operations," in this Management's Discussion.
NiSource Next: We are executing on a defined, comprehensive, multi-year program designed to deliver long-term safety, sustainable capability enhancements and cost optimization improvements. This program is advancing the high priority we place on safety and risk mitigation, further enabling our safety management system, and enhancing the customer experience. NiSource Next is designed to (i) leverage our current scale, (ii) utilize technology, (iii) define clear roles and accountability with our leaders and employees, and (iv) standardize our processes to focus on operational rigor, quality management and continuous improvement.
COVID-19: The safety of our employees and customers, while providing essential services during the COVID-19 pandemic, is paramount. We continue to take a proactive, coordinated approach intended to prevent, mitigate and respond to COVID-19 by utilizing our Incident Command System (ICS). The ICS includes members of our executive council, a medical review professional, and members of functional teams from across our company. The ICS monitors state-by-state conditions and determines steps to conduct our operations safely for employees and customers.
We have implemented procedures designed to protect our employees who work in the field and who continue to work in operational and corporate facilities, including social distancing, wearing face coverings and more frequent cleaning of equipment and facilities. We have also implemented work-from-home policies and practices. As local circumstances permit, we are beginning previously delayed work that requires customer interaction. We continue to employ physical and cybersecurity measures to ensure that our operational and support systems remain functional. Our actions to date have mitigated the spread of COVID-19 amongst our employees and principal field contractors. We are also continuously evaluating changes to CDC guidance, and updating our safety measures accordingly, in order to ensure employee and customer safety during this pandemic.
ITEM 2.MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (continued)
NiSource Inc.
We are following all federal, state, and local guidelines related to the COVID-19 vaccinations and are encouraging employees to receive the vaccine.
Since the beginning of the COVID-19 pandemic, we have been helping our customers navigate this challenging time. We plan to continue our payment assistance programs and customer education and awareness of energy assistance programs such as the Low Income Home Energy Assistance Program (LIHEAP) to help customers deal with the impact of the pandemic. Regulatory deferrals for certain costs have been allowed by all of our state regulatory commissions.
We continue to monitor how COVID-19 is affecting our workforce, customers, suppliers, operations, financial results and cash flow. The extent of the impact in the future will vary and depend on the duration and severity of the impact on the global, national and local economies. For information on the impacts of COVID-19 for the three and six months ended June 30, 2021, the state-specific suspension of disconnections, and COVID-19 regulatory filings see Note 3, “Revenue Recognition,” and Note 8, “Regulatory Matters,” in the Notes to Condensed Consolidated Financial Statements (unaudited).
Summary of Consolidated Financial Results
A summary of our consolidated financial results for the three and six months ended June 30, 2021 and 2020 are presented below:
Three Months Ended June 30,
Six Months Ended June 30,
(in millions, except per share amounts)
2021
2020
Favorable (Unfavorable)
2021
2020
Favorable (Unfavorable)
Operating Revenues
$
986.0
$
962.7
$
23.3
$
2,531.6
$
2,568.2
$
(36.6)
Operating Expenses
Cost of energy
228.3
188.4
(39.9)
705.1
650.8
(54.3)
Other Operating Expenses
615.5
682.6
67.1
1,251.1
1,677.5
426.4
Total Operating Expenses
843.8
871.0
27.2
1,956.2
2,328.3
372.1
Operating Income
142.2
91.7
50.5
575.4
239.9
335.5
Total Other Deductions, net
(72.1)
(90.5)
18.4
(146.2)
(178.0)
31.8
Income Taxes
13.2
5.9
(7.3)
75.8
(9.0)
(84.8)
Net Income (Loss)
56.9
(4.7)
61.6
353.4
70.9
282.5
Net loss attributable to noncontrolling interest
(3.4)
—
3.4
(2.4)
—
2.4
Net Income (Loss) Attributable to NiSource
60.3
(4.7)
65.0
355.8
70.9
284.9
Preferred dividends
(13.8)
(13.8)
—
(27.6)
(27.6)
—
Net Income (Loss) Available to Common Shareholders
46.5
(18.5)
65.0
328.2
43.3
284.9
Earnings (Loss) Per Share
Basic Earnings (Loss) Per Share
$
0.12
$
(0.05)
$
0.17
$
0.84
$
0.11
$
0.73
Diluted Earnings (Loss) Per Share
$
0.11
$
(0.05)
$
0.16
$
0.80
$
0.11
$
0.69
The majority of the cost of energy in both segments are tracked costs that are passed through directly to the customer, resulting in an equal and offsetting amount reflected in operating revenues.
On a consolidated basis, we reported a net income available to common shareholders of $46.5 million, or $0.11 per diluted share for the three months ended June 30, 2021, compared to a net loss available to common shareholders of $18.5 million, or $0.05 per diluted share for the same period in 2020. The increase in income was primarily due to the loss on sale of the Massachusetts business in 2020, as well as lower operating expenses offset by lower operating revenues due to the sale of the Massachusetts business. Additionally, the increase in income was driven by revenue increases from new rates offset by higher employee and administrative expenses and outside services during the three months ended June 30, 2021 compared to the same period in 2020.
For the six months ended June 30, 2021, we reported net income available to common shareholders of $328.2 million, or $0.80 per diluted share compared to net income available to common shareholders of $43.3 million, or $0.11 per diluted share for the same period in 2020. The drivers for this increase were consistent with that of the quarter-to-date period. For additional information on operating income variance drivers see "Results and Discussion of Segment Operation" for Gas and Electric Operations in this Management's Discussion.
ITEM 2.MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (continued)
NiSource Inc.
Other Deductions, net
Other deductions, net reduced income by $72.1 million during the three months ended June 30, 2021 compared to a reduction in income of $90.5 million in the same period in 2020. This change was primarily driven by lower short-term and long-term debt interest due to lower balances on short-term debt, and lower rates on commercial paper and long-term debt during the three months ended June 30, 2021 compared to the same period in 2020. See Note 15, "Short-Term Borrowings," in the Notes to the Condensed Consolidated Financial Statements (unaudited) for additional information.
Other deductions, net reduced income by $146.2 million during the six months ended June 30, 2021 compared to a reduction in income of $178.0 million in the same period in 2020. The drivers for this change were consistent with that of the quarter-to-date period.
Income Taxes
Refer to Note 12, "Income Taxes," in the Notes to Condensed Consolidated Financial Statements (unaudited) for information on income taxes and the change in the effective tax rate.
RESULTS AND DISCUSSION OF SEGMENT OPERATIONS
Presentation of Segment Information
Our operations are divided into two primary reportable segments: Gas Distribution Operations and Electric Operations. We primarily evaluate segment results based on operating income. The remainder of our operations, which are not significant enough on a stand-alone basis to warrant treatment as an operating segment, are presented as "Corporate and Other" within the Notes to the Condensed Consolidated Financial Statements (unaudited) and primarily are comprised of interest expense on holding company debt, and unallocated corporate costs and activities.
ITEM 2.MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (continued)
NiSource Inc.
Gas Distribution Operations
Financial and operational data for the Gas Distribution Operations segment for the three and six months ended June 30, 2021 and 2020 are presented below:
Three Months Ended June 30,
Six Months Ended June 30,
(in millions)
2021
2020
Favorable (Unfavorable)
2021
2020
Favorable (Unfavorable)
Operating Revenues
$
577.3
$
609.2
$
(31.9)
$
1,716.2
$
1,840.2
$
(124.0)
Operating Expenses
Cost of energy
129.0
119.2
(9.8)
508.0
496.6
(11.4)
Operation and maintenance
243.9
263.1
19.2
492.7
593.2
100.5
Depreciation and amortization
93.6
86.8
(6.8)
186.5
183.3
(3.2)
Loss on sale of fixed assets and impairments, net
—
84.4
84.4
8.1
364.6
356.5
Other taxes
49.6
54.0
4.4
112.8
122.3
9.5
Total Operating Expenses
516.1
607.5
91.4
1,308.1
1,760.0
451.9
Operating Income
$
61.2
$
1.7
$
59.5
$
408.1
$
80.2
$
327.9
Revenues
Residential
$
380.8
$
410.6
$
(29.8)
$
1,163.1
$
1,233.9
$
(70.8)
Commercial
127.4
124.1
3.3
400.3
398.1
2.2
Industrial
44.4
48.8
(4.4)
102.6
123.3
(20.7)
Off-System
17.0
8.0
9.0
31.4
26.7
4.7
Other
7.7
17.7
(10.0)
18.8
58.2
(39.4)
Total
$
577.3
$
609.2
$
(31.9)
$
1,716.2
$
1,840.2
$
(124.0)
Sales and Transportation (MMDth)
Residential
30.7
39.8
(9.1)
149.1
158.3
(9.2)
Commercial
27.2
28.4
(1.2)
101.5
102.1
(0.6)
Industrial
124.7
124.2
0.5
261.1
271.0
(9.9)
Off-System
6.2
4.1
2.1
11.6
15.3
(3.7)
Other
—
—
—
0.2
0.2
—
Total
188.8
196.5
(7.7)
523.5
546.9
(23.4)
Heating Degree Days
606
728
(122)
3,309
3,168
141
Normal Heating Degree Days
551
563
(12)
3,405
3,460
(55)
% Colder (Warmer) than Normal
10
%
29
%
(3)
%
(8)
%
Gas Distribution Customers
Residential
2,950,269
3,237,131
(286,862)
Commercial
252,235
282,482
(30,247)
Industrial
4,943
5,983
(1,040)
Other
3
3
—
Total
3,207,450
3,525,599
(318,149)
Comparability of operation and maintenance expenses, depreciation and amortization, and other taxes may be impacted by regulatory, depreciation and tax trackers that allow for the recovery in rates of certain costs.
ITEM 2.MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (continued)
NiSource Inc.
Gas Distribution Operations
Three and Six Months Ended June 30, 2021 vs. June 30, 2020 Operating Income
For the three months ended June 30, 2021, Gas Distribution Operations reported operating income of $61.2 million, an increase of $59.5 million from the comparable 2020 period. For the six months ended June 30, 2021, Gas Distribution Operations reported operating income of $408.1 million, an increase of $327.9 million from the comparable 2020 period.
Operating revenues for the three months ended June 30, 2021 were $577.3 million, a decrease of $31.9 million from the same period in 2020. Operating revenues for the six months ended June 30, 2021 were $1,716.2 million, a decrease of $124.0 million from the same period in 2020.
Favorable (Unfavorable)
Changes in Operating Revenues (in millions)
Three Months Ended June 30, 2021 vs 2020
Six Months Ended June 30, 2021 vs 2020
Revenues associated with the Massachusetts Business in 2020
$
(55.6)
$
(178.1)
The effects of colder (warmer) weather in 2021 compared to 2020
(2.1)
13.5
New rates from base rate proceedings, infrastructure replacement programs and Columbia of Ohio's CEP
22.6
60.6
The effects of customer growth
1.3
4.7
Other
3.9
1.8
Change in operating revenues (before cost of energy and other tracked items)
$
(29.9)
$
(97.5)
Operating revenues offset in operating expense
Higher cost of energy billed to customers
31.9
113.2
Cost of energy associated with the Massachusetts Business in 2020
(22.1)
(101.8)
Operation and maintenance trackers associated with the Massachusetts Business in 2020
(7.1)
(31.2)
Lower operation and maintenance, depreciation, and tax trackers
ITEM 2.MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (continued)
NiSource Inc.
Gas Distribution Operations
Operating expenses were $91.4 million lower for the three months ended June 30, 2021 and $451.9 million lower for the six months ended June 30, 2021 compared to the same respective periods in 2020.
Favorable (Unfavorable)
Changes in Operating Expenses (in millions)
Three Months Ended June 30, 2021 vs 2020
Six Months Ended June 30, 2021 vs 2020
Loss on sale of the Massachusetts Business of zero and $6.9 million in 2021 compared to $84.4 million and $364.6 million in 2020, respectively
$
84.4
$
357.7
Operating expenses associated with the Massachusetts Business in 2020
58.6
126.8
Decreased operating expenses primarily related to the impact of COVID-19 in 2020
6.8
8.3
Higher employee and administrative expenses
(19.9)
(13.8)
Higher outside services expenses
(12.4)
(10.1)
Severance and outside services expense related to the NiSource Next initiative
(7.5)
(14.0)
Higher depreciation and amortization expense
(7.2)
(13.0)
Higher property tax expense
(3.2)
(4.5)
Higher environmental costs
(2.1)
(2.6)
Higher corporate insurance costs
(1.8)
(3.5)
Other
(6.3)
(5.9)
Change in operating expenses (before cost of energy and other tracked items)
$
89.4
$
425.4
Operating expenses offset in operating revenue
Higher cost of energy billed to customers
(31.9)
(113.2)
Cost of energy associated with the Massachusetts Business in 2020
22.1
101.8
Operation and maintenance trackers associated with the Massachusetts Business in 2020
7.1
31.2
Lower operation and maintenance, depreciation, and tax trackers
4.7
6.7
Total change in operating expense
$
91.4
$
451.9
Weather
In general, we calculate the weather-related revenue variance based on changing customer demand driven by weather variance from normal heating degree days, net of weather normalization mechanisms. Our composite heating degree days reported do not directly correlate to the weather-related dollar impact on the results of Gas Distribution Operations. Heating degree days experienced during different times of the year or in different operating locations may have more or less impact on volume and dollars depending on when and where they occur. When the detailed results are combined for reporting, there may be weather-related dollar impacts on operations when there is not an apparent or significant change in our aggregated composite heating degree day comparison.
Weather in the Gas Distribution Operations service territories for the three months ended June 30, 2021 was about 10% colder than normal and about 17% warmer than the same period in 2020, leading to decreased operating revenues of $2.1 million for the three months ended June 30, 2021 compared to the same period in 2020.
Weather in the Gas Distribution Operations service territories for the six months ended June 30, 2021 was about 3% warmer than normal and about 4% colder than the same period in 2020, leading to increased operating revenues of $13.5 million for the six months ended June 30, 2021 compared to the same period in 2020.
Throughput
Total volumes sold and transported for the three months ended June 30, 2021 were 188.8 MMDth, compared to 196.5 MMDth for the same period in 2020. This decrease is primarily attributable to the sale of the Massachusetts Business and the effects of warmer weather during the three months ended June 30, 2021 compared to the same period in 2020.
ITEM 2.MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (continued)
NiSource Inc.
Gas Distribution Operations
Total volumes sold and transported for the six months ended June 30, 2021 were 523.5 MMDth, compared to 546.9 MMDth for the same period in 2020. This decrease is primarily attributable to the sale of the Massachusetts Business, offset by the effects of colder weather during the six months ended June 30, 2021 compared to the same period in 2020.
Commodity Price Impact
Cost of energy for the Gas Distribution Operations segment is principally comprised of the cost of natural gas used while providing transportation and distribution services to customers. All of our Gas Distribution Operations companies have state-approved recovery mechanisms that provide a means for full recovery of prudently incurred gas costs. These are tracked costs that are passed through directly to the customer, and the gas costs included in revenues are matched with the gas cost expense recorded in the period. The difference is recorded on the Condensed Consolidated Balance Sheets (unaudited) as under-recovered or over-recovered gas cost to be included in future customer billings. Therefore, increases in these tracked operating expenses are offset by increases in operating revenues and have essentially no impact on net income.
Certain Gas Distribution Operations companies continue to offer choice opportunities, where customers can choose to purchase gas from a third-party supplier, through regulatory initiatives in their respective jurisdictions. These programs serve to further reduce our exposure to gas prices.
Columbia of Massachusetts Asset Sale
On October 9, 2020, we completed the sale of our Massachusetts Business. In March 2021, we reached an agreement with Eversource regarding the final purchase price, including net working capital adjustments, which resulted in a pre-tax loss for the three and six months ended June 30, 2021 of zero and $6.9 million, respectively. The total loss on the sale as of June 30, 2021 is $419.3 million based on asset and liability balances as of the close of the transaction on October 9, 2020, transaction costs and the final purchase price. The pre-tax loss is presented as "Loss (gain) on sale of assets, net" on the Condensed Statements of Consolidated Income (Loss) (unaudited).
ITEM 2.MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (continued)
NiSource Inc.
Electric Operations
Financial and operational data for the Electric Operations segment for the three and six months ended June 30, 2021 and 2020 are presented below:
Three Months Ended June 30,
Six Months Ended June 30,
(in millions)
2021
2020
Favorable (Unfavorable)
2021
2020
Favorable (Unfavorable)
Operating Revenues
403.7
$
356.4
47.3
806.4
$
733.9
$
72.5
Operating Expenses
Cost of energy
99.3
69.2
(30.1)
197.1
154.2
(42.9)
Operation and maintenance
127.3
108.0
(19.3)
246.4
228.9
(17.5)
Depreciation and amortization
83.7
80.6
(3.1)
167.1
159.5
(7.6)
Other taxes
13.8
11.7
(2.1)
28.3
25.9
(2.4)
Total Operating Expenses
324.1
269.5
(54.6)
638.9
568.5
(70.4)
Operating Income
$
79.6
$
86.9
$
(7.3)
$
167.5
$
165.4
$
2.1
Revenues
Residential
$
131.9
$
124.0
$
7.9
$
261.1
$
243.2
$
17.9
Commercial
129.9
109.8
20.1
252.8
230.0
22.8
Industrial
119.2
86.5
32.7
242.3
195.6
46.7
Wholesale
3.1
2.8
0.3
6.5
6.0
0.5
Other
19.6
33.3
(13.7)
43.7
59.1
(15.4)
Total
$
403.7
$
356.4
$
47.3
$
806.4
$
733.9
$
72.5
Sales (Gigawatt Hours)
Residential
821.0
834.0
(13.0)
1,625.6
1,589.5
36.1
Commercial
904.2
831.8
72.4
1,772.1
1,710.5
61.6
Industrial
2,150.8
1,467.5
683.3
4,214.1
3,538.6
675.5
Wholesale
12.4
4.9
7.5
44.5
76.3
(31.8)
Other
20.3
21.5
(1.2)
47.6
49.7
(2.1)
Total
3,908.7
3,159.7
749.0
7,703.9
6,964.6
739.3
Cooling Degree Days
318
292
26
318
292
26
Normal Cooling Degree Days
239
239
—
239
239
—
% Warmer than Normal
33
%
22
%
33
%
22
%
Electric Customers
Residential
420,347
417,251
3,096
Commercial
57,637
57,236
401
Industrial
2,148
2,164
(16)
Wholesale
719
723
(4)
Other
2
2
—
Total
480,853
477,376
3,477
Comparability of operation and maintenance expenses and depreciation and amortization may be impacted by regulatory and depreciation trackers that allow for the recovery in rates of certain costs.
Three and Six Months Ended June 30, 2021 vs. June 30, 2020 Operating Income
For the three months ended June 30, 2021, Electric Operations reported operating income of $79.6 million, a decrease of $7.3 million from the comparable 2020 period. For the six months ended June 30, 2021, Electric Operations reported operating income of $167.5 million, an increase of $2.1 million from the comparable 2020 period.
ITEM 2.MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (continued)
NiSource Inc.
Electric Operations
Operating revenues for the three months ended June 30, 2021 were $403.7 million, an increase of $47.3 million from the same period in 2020. Operating revenues for the six months ended June 30, 2021 were $806.4 million, an increase of $72.5 million from the same period in 2020.
Favorable (Unfavorable)
Changes in Operating Revenues (in millions)
Three Months Ended June 30, 2021 vs 2020
Six Months Ended June 30, 2021 vs 2020
Increased customer usage, primarily driven by industrial customers
$
11.4
$
16.2
The effects of warmer weather in 2021 compared to 2020
3.3
4.2
New rates from infrastructure improvement and DSM programs
3.2
6.0
The effects of customer growth
1.1
2.1
Increased fuel handling costs
(4.8)
(6.5)
Other
0.6
2.8
Change in operating revenues (before cost of energy and other tracked items)
$
14.8
$
24.8
Operating revenues offset in operating expense
Higher cost of energy billed to customers
30.1
42.9
Higher operation and maintenance and depreciation trackers
2.4
4.8
Total change in operating revenues
$
47.3
$
72.5
Operating expenses were $54.6 million higher for the three months ended June 30, 2021 compared to the same period in 2020. Operating expenses were $70.4 million higher for the six months ended June 30, 2021 compared to the same period in 2020.
Favorable (Unfavorable)
Changes in Operating Expenses (in millions)
Three Months Ended June 30, 2021 vs 2020
Six Months Ended June 30, 2021 vs 2020
Higher generation-related maintenance expense
$
(8.5)
$
(12.1)
Higher employee and administrative expenses
(8.4)
(4.3)
Higher materials and supplies expenses
(7.9)
(7.6)
Severance and outside services expenses related to the NiSource Next initiative
(3.5)
(5.6)
Increased depreciation primarily due to additional plant placed in service
(1.9)
(5.3)
Decreased operating expenses primarily related to the impact of COVID-19 in 2020
4.3
4.9
Decreased environmental costs
2.3
9.1
Other
1.5
(1.8)
Change in operating expenses (before cost of energy and other tracked items)
$
(22.1)
$
(22.7)
Operating expenses offset in operating revenue
Higher cost of energy billed to customers
(30.1)
(42.9)
Higher operation and maintenance and depreciation trackers
(2.4)
(4.8)
Total change in operating expense
$
(54.6)
$
(70.4)
Weather
In general, we calculate the weather-related revenue variance based on changing customer demand driven by weather variance from normal heating or cooling degree days. Our composite heating or cooling degree days reported do not directly correlate to the weather-related dollar impact on the results of Electric Operations. Heating or cooling degree days experienced during different times of the year may have more or less impact on volume and dollars depending on when they occur. When the
ITEM 2.MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (continued)
NiSource Inc.
Electric Operations
detailed results are combined for reporting, there may be weather-related dollar impacts on operations when there is not an apparent or significant change in our aggregated composite heating or cooling degree day comparison.
Weather in the Electric Operations’ territories for the three months ended June 30, 2021 was about 33% warmer than normal and about 9% warmer than the same period in 2020, leading to increased operating revenues of $3.3 million for the three months ended June 30, 2021 compared to the same period in 2020.
Weather in the Electric Operations’ territories for the six months ended June 30, 2021 was about 33% warmer than normal and about 9% warmer than the same period in 2020, leading to increased operating revenues of $4.2 million for the six months ended June 30, 2021 compared to the same period in 2020.
Sales
Electric Operations sales for the three months ended June 30, 2021 were 3,908.7 GWh, an increase of 749.0 GWh compared to the same period in 2020. This increase was primarily attributable to decreased usage by industrial and commercial customers during the three months ended June 30, 2020 due to COVID-19.
Electric Operations sales for the six months ended June 30, 2021 were 7,703.9 GWh, an increase of 739.3 GWh compared to the same period in 2020. This increase was primarily attributable to decreased usage by industrial and commercial customers during the three months ended June 30, 2020 due to COVID-19. There was no significant variance during the first three months of 2021 compared to the same period in 2020.
Commodity Price Impact
Cost of energy for the Electric Operations segment is principally comprised of the cost of coal, related handling costs, natural gas purchased for internal generation of electricity at NIPSCO, and the cost of power purchased from third-party generators of electricity. NIPSCO has a state-approved recovery mechanism that provides a means for full recovery of prudently incurred fuel costs. The majority of these fuel costs are passed through directly to the customer, and the fuel costs included in operating revenues are matched with the fuel cost expense recorded in the period. The difference is recorded on the Condensed Consolidated Balance Sheets (unaudited) as under-recovered or over-recovered fuel cost to be included in future customer billings. Therefore, increases in these tracked operating expenses are offset by increases in operating revenues and have essentially no impact on net income.
Electric Supply and Generation Transition
NIPSCO continues to execute on an electric generation transition consistent with the preferred pathway from its 2018 Integrated Resource Plan, which outlines plans to retire all of its remaining coal-fired generation by 2028, to be replaced by lower-cost, reliable and cleaner options. The plan is expected to be a key element of a 90% reduction in NiSource's greenhouse gas emissions by 2030 compared with 2005 levels, and to save NIPSCO electric customers more than $4 billion over 30 years. We expect to have incremental capital investment requirements of approximately $2.0 billion, primarily in 2022 and 2023. On March 11, 2021, NIPSCO submitted separate Attachment Y Notices for Units 14 and 15 seeking a suspension date of October 1, 2021 for both coal fired units at R.M. Schahfer Generating Station. On May 28, 2021, NIPSCO received approval from MISO to suspend and retire these two units on October 1, 2021. The remaining two units are still scheduled to be retired in 2023. Refer to Note 7, "Property, Plant and Equipment," and Note 16-E, "Other Matters," in the Notes to Condensed Consolidated Financial Statements (unaudited) for further information.
The current replacement plan primarily includes renewable sources of energy, including wind, solar, and battery storage to be obtained through a combination of NIPSCO ownership and PPAs. NIPSCO has executed several PPAs to purchase 100% of the output from renewable generation facilities at a fixed price per MWh. Each facility supplying the energy will have an associated nameplate capacity, and payments under the PPAs will not begin until the associated generation facility is constructed by the owner/seller. NIPSCO has also executed several BTAs with developers to construct renewable generation facilities.
ITEM 2.MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (continued)
NiSource Inc.
Liquidity and Capital Resources
We continually evaluate the availability of adequate financing to fund our ongoing business operations, working capital and core safety and infrastructure investment programs. Our financing is sourced through cash flow from operations and the issuance of debt and/or equity. External debt financing is provided primarily through the issuance of long-term debt, accounts receivable securitization programs and our $1.5 billion commercial paper program, which is backstopped by our committed revolving credit facility with a total availability from third-party lenders of $1.85 billion. The commercial paper program and credit facility provide cost-effective, short-term financing until it can be replaced with a balance of long-term debt and equity financing that achieves our desired capital structure. We utilize an ATM equity program that allows us to issue and sell shares of our common stock up to an aggregate issuance of $750.0 million through December 31, 2023. On April 19, 2021, we completed the sale of 8.625 million Equity Units, which provided net proceeds of $835.5 million, after underwriting and issuance costs. We intend to use the net proceeds from the offering for renewable generation investments and general corporate purposes, including additions to working capital and repayment of existing indebtedness.
We believe these sources provide adequate capital to fund our operating activities and capital expenditures in 2021 and beyond.
Greater Lawrence Incident: As discussed in Note 16, “Other Commitments and Contingencies,” in the Notes to the Condensed Consolidated Financial Statements (unaudited), due to the inherent uncertainty of litigation, there can be no assurance that the outcome or resolution of any particular claim related to the Greater Lawrence Incident will not continue to have an adverse impact on our cash flows. Through income generated from operating activities, amounts available under the short-term revolving credit facility, and our ability to access capital markets, we believe we have adequate capital available to settle remaining anticipated claims associated with the Greater Lawrence Incident.
Operating Activities
Net cash from operating activities for the six months ended June 30, 2021 was $703.0 million, a decrease of $4.7 million compared to the six months ended June 30, 2020. This decrease was primarily driven by $140.7 million of decreased cash inflows related to the under collection of gas and fuel costs. This was offset by a year over year decrease in net payments related to the Greater Lawrence Incident. During 2021, we paid approximately $11.0 million compared to $162.0 million of payments during the same period in 2020.
Investing Activities
Net cash used for investing activities for the six months ended June 30, 2021 was $862.4 million, a decrease of $24.2 million compared to the six months ended June 30, 2020. This decrease was driven by lower capital expenditures associated with the Massachusetts Business in 2020. We project total 2021 capital expenditures to be approximately $1.9 to $2.1 billion.
ITEM 2.MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (continued)
NiSource Inc.
Regulatory Capital Improvement Programs. In 2021, we continue to move forward on core infrastructure and environmental investment programs supported by complementary regulatory and customer initiatives across all six states of our operating area.
The following table describes the most recent vintage of our regulatory programs to recover infrastructure replacement and other federally mandated compliance investments currently in rates and those pending commission approval:
(in millions)
Company
Program
Incremental Revenue
Incremental Capital Investment
Investment Period
Costs Covered(1)
Rates Effective
Columbia of Ohio
IRP - 2021
22.2
212.6
1/20-12/20
Replacement of (1) hazardous service lines, (2) cast iron, wrought iron, uncoated steel, and bare steel pipe, (3) natural gas risers prone to failure and (4) installation of AMR devices.
May 2021
Columbia of Ohio
CEP - 2021
18.0
177.2
1/20-12/20
Assets not included in the IRP.
September 2021
NIPSCO - Gas
TDSIC 2
1.8
52.3
7/20-12/20
New or replacement projects undertaken for the purpose of safety, reliability, system modernization or economic development.
July 2021
NIPSCO - Gas(2)
FMCA 6
(2.1)
20.7
10/20-3/21
Project costs to comply with federal mandates.
October 2021
Columbia of Pennsylvania(3)
DSIC - Q4 2020
0.8
25.0
9/20-11/20
Eligible project costs including piping, couplings, gas service lines, excess flow valves, risers, meter bars, meters, and other related capitalized cost, to improve the distribution system.
January 2021
Columbia of Virginia
SAVE - 2021
5.2
46.4
1/21-12/21
Replacement projects that (1) enhance system safety or reliability, or (2) reduce, or potentially reduce, greenhouse gas emissions.
January 2021
Columbia of Kentucky
SMRP - 2021
2.6
40.0
1/21-12/21
Replacement of mains and inclusion of system safety investments.
May 2021
Columbia of Maryland
STRIDE - 2021
1.3
16.9
1/21-12/21
Pipeline upgrades designed to improve public safety or infrastructure reliability.
January 2021
NIPSCO - Electric(4)(5)
TDSIC - 8
(2.0)
73.5
8/20-1/21
New or replacement projects undertaken for the purpose of safety, reliability, system modernization or economic development.
August 2021
(1)Programs do not include any costs already included in base rates.
(2)Decrease in incremental revenue due to lower O&M expenses as compared to the prior filing.
(3)Effective January 23, 2021, Columbia of Pennsylvania's DSIC rate was set to zero due to the inclusion of the incremental capital and revenue in base rates following the Pennsylvania PUC's Final Order in the 2020 rate case.
(4)Decrease in incremental revenue is due to lower depreciation expense (pre-2018 base rate case vs. post-2018 base rate case).
(5)On April 1, 2021, NIPSCO filed a notice with the IURC that it intended to terminate its current Electric TDSIC plan effective May 31, 2021. NIPSCO filed for a new electric TDSIC plan on June 1, 2021. An order is expected by the end of 2021.
Financing Activities
Common Stock and Preferred Stock. Refer to Note 5, “Equity,” in the Notes to Condensed Consolidated Financial Statements (unaudited) for information on common and preferred stock activity.
Short-term Debt and Sale of Trade Accounts Receivables. Refer to Note 15, “Short-Term Borrowings,” in the Notes to Condensed Consolidated Financial Statements (unaudited) for information on short-term debt activity, including sale of trade accounts receivable.
Equity Unit Sale. Refer to Note 5, “Equity,” in the Notes to Condensed Consolidated Financial Statements (unaudited) for information on equity units activity.
Non-controlling Interest. Refer to Note 14, "Variable Interest Entities," in the Notes to Condensed Consolidated Financial Statements (unaudited) for information on contributions from non-controlling interest activity.
Net Available Liquidity. As of June 30, 2021, an aggregate of $2,159.6 million of net liquidity was available, including cash and credit available under the revolving credit facility.
ITEM 2.MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (continued)
NiSource Inc.
The following table displays our liquidity position as of June 30, 2021 and December 31, 2020:
(in millions)
June 30, 2021
December 31, 2020
Current Liquidity
Revolving Credit Facility
$
1,850.0
$
1,850.0
Accounts Receivable Program(1)
246.2
273.3
Less:
Commercial Paper
—
503.0
Letters of Credit Outstanding Under Credit Facility
14.1
15.2
Add:
Cash and Cash Equivalents
77.5
116.5
Net Available Liquidity
$
2,159.6
$
1,721.6
(1)Represents the lesser of the seasonal limit or maximum borrowings supportable by the underlying receivables.
Debt Covenants. We are subject to financial covenants under our revolving credit facility, which require us to maintain a debt to capitalization ratio that does not exceed 70%. As of June 30, 2021, the ratio was 58.6%.
Credit Ratings. The credit rating agencies periodically review our ratings, taking into account factors such as our capital structure and earnings profile. The following table includes our and NIPSCO's credit ratings and ratings outlook as of June 30, 2021.
A credit rating is not a recommendation to buy, sell, or hold securities, and may be subject to revision or withdrawal at any time by the assigning rating organization.
S&P
Moody's
Fitch
Rating
Outlook
Rating
Outlook
Rating
Outlook
NiSource
BBB+
Stable
Baa2
Stable
BBB
Stable
NIPSCO
BBB+
Stable
Baa1
Stable
BBB
Stable
Commercial Paper
A-2
Stable
P-2
Stable
F2
Stable
Certain of our subsidiaries have agreements that contain “ratings triggers” that require increased collateral if our credit rating or the credit ratings of certain of our subsidiaries are below investment grade. These agreements are primarily for insurance purposes and for the physical purchase or sale of power. As of June 30, 2021, the collateral requirement that would be required in the event of a downgrade below the ratings trigger levels would amount to approximately $50.3 million. In addition to agreements with ratings triggers, there are other agreements that contain “adequate assurance” or “material adverse change” provisions that could necessitate additional credit support such as letters of credit and cash collateral to transact business.
Equity. Our authorized capital stock consists of 620,000,000 shares, $0.01 par value, of which 600,000,000 are common stock and 20,000,000 are preferred stock. As of June 30, 2021, 392,328,441 shares of common stock and 1,302,500 shares of preferred stock were outstanding.
Contractual Obligations. A summary of contractual obligations is included in the Company’s Annual Report on Form 10-K for the year ended December 31, 2020. Other than the purchase contract liability related to our Equity Units, discussed in Note 5, "Equity," in the Notes to the Condensed Consolidated Financial Statements (unaudited), there were no material changes from year-end during the six months ended June 30, 2021.
Guarantees and Indemnities. We and certain of our subsidiaries enter into various agreements providing financial or performance assurance to third parties on behalf of certain subsidiaries as a part of normal business. Refer to Note 16, “Other Commitments and Contingencies,” in the Notes to the Condensed Consolidated Financial Statements (unaudited) for information on guarantees.
ITEM 2.MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (continued)
NiSource Inc.
Regulatory and Other Matters
Cost Recovery and Trackers
Comparability of our line item operating results is impacted by regulatory trackers that allow for the recovery in rates of certain costs such as those described below. Increases in the expenses that are subject to approved regulatory tracker mechanisms generally lead to increased regulatory assets, which ultimately result in a corresponding increase in operating revenues and, therefore, have essentially no impact on total operating income results. Certain approved regulatory tracker mechanisms allow for abbreviated regulatory proceedings in order for the operating companies to quickly implement revised rates and recover associated costs.
A portion of the Gas Distribution revenue is related to the recovery of gas costs, the review and recovery of which occurs through standard regulatory proceedings. All states in our operating area require periodic review of actual gas procurement activity to determine prudence and to confirm the recovery of prudently incurred energy commodity costs supplied to 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. As a result, Gas Distribution Operations have pursued changes in rate design to more effectively match recoveries with costs incurred. Columbia of Ohio has adopted a straight fixed variable rate design that closely links the recovery of fixed costs with fixed charges. Columbia of Maryland and Columbia of Virginia have regulatory approval for weather and revenue normalization adjustments for certain customer classes, which adjust monthly revenues that exceed or fall short of approved levels. Columbia of Pennsylvania continues to operate its pilot residential weather normalization adjustment and also has a fixed customer charge. This weather normalization adjustment only adjusts revenues when actual weather compared to normal varies by more than 3%. Columbia of Kentucky incorporates a weather normalization adjustment for certain customer classes and also has a fixed customer charge. In a prior gas base rate proceeding, NIPSCO implemented a higher fixed customer charge for residential and small customer classes moving toward recovering more of its fixed costs through a fixed recovery charge, but has no weather or usage protection mechanism.
A portion of the Electric Operations revenue is related to the recovery of fuel costs to generate power and the fuel costs related to purchased power. These costs are recovered through a FAC, which is updated quarterly to reflect actual costs incurred to supply electricity to customers.
While increased efficiency of electric appliances and improvements in home building codes and standards has similarly impacted the average use per electric customer in recent years, NIPSCO expects a future trend with increases in per customer usage driven by increasing electric applications. Further growth is anticipated as electric vehicles become more prevalent. These ongoing changes in use of electricity will likely lead to development of innovative rate designs, and NIPSCO will continue efforts to design rates that increase the certainty of recovery of fixed costs.
ITEM 2.MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (continued)
NiSource Inc.
Regulatory and Other Matters
Rate Case Actions
The following table describes current rate case actions as applicable in each of our jurisdictions net of tracker impacts:
(in millions)
Company
Proposed ROE
Approved ROE
Requested Incremental Revenue
Approved Incremental Revenue
Filed
Status
Rates Effective
Columbia of Pennsylvania(1)
9.86
%
9.86
%
$
76.8
$
63.5
April 24, 2020
Approved February 19, 2021
January 2021
Columbia of Pennsylvania
10.95
%
In process
$
98.3
In process
March 30, 2021
Order Expected Q4 2021
December 2021
Columbia of Maryland
10.85
%
In process
$
4.8
In process
May 14, 2021
Order Expected Q4 2021
December 2021
Columbia of Kentucky
10.30
%
In process
$
26.7
In process
May 28, 2021
Order Expected Q1 2022
January 2022
Columbia of Ohio
10.95
%
In process
$
221.4
In process
June 30, 2021
Order Expected Q3 2022
July 2022
(1)The 9.86% ROE and the $76.8 million requested incremental revenue stated above reflect compromise positions taken by Columbia of Pennsylvania during the briefing stages of its 2020 base rate case. In its initial filing on April 24, 2020, Columbia of Pennsylvania proposed an ROE of 10.95% and requested incremental revenue of $100.4 million. A Final Order from the Pennsylvania PUC was received on February 19, 2021 for rates effective retroactive to January 23, 2021. On March 8, 2021, the Pennsylvania Office of Consumer Advocate filed a Petition for Reconsideration, seeking to have the Pennsylvania PUC modify its February 19 Final Order. On April 15, 2021, the Pennsylvania PUC issued an Opinion and Order denying the Office of Consumer Advocate’s Petition. Parties have 30 days in which to file an appeal. The OCA did not file a Notice of Appeal by the Commission’s May 17, 2021 due date. CPA began back billing customers for usage from January 23, 2021 at the new rates beginning March 20, 2021.
COVID-19 Regulatory Deferrals
In addition to the cost deferred to a regulatory asset as noted in Note 8, "Regulatory Matters," in the Notes to Condensed Consolidated Financial Statements (unaudited), certain states have permitted us to track lost late and disconnect fee revenues due to the pandemic. While these costs do not qualify as regulatory assets under ASC 980, we will consider seeking recovery of these costs in future regulatory proceedings.
PHMSA Regulations
On December 27, 2020, the Protecting Our Infrastructure of Pipelines and Enhancing Safety (PIPES) Act of 2020 was signed into law reauthorizing funding for federal pipeline safety programs through September 30, 2023. Among other things, the PIPES Act requires that PHMSA revise the pipeline safety regulations to require operators to update, as needed, their existing distribution integrity management plans, emergency response plans, and O&M plans. The PIPES Act also requires PHMSA to adopt new requirements for managing records and updating, as necessary existing district regulator stations to eliminate common modes of failure that can lead to overpressurization. PHMSA must also require that operators implement leak detection and repair programs that meet safety needs and protect the environment, require the use of advance leak detection practices and technologies, and require operators to be able to locate and categorize all leaks that are hazardous to human safety or the environment, or that can become hazardous. Natural gas companies, including the Company, may see increased costs depending on how PHMSA implements the new mandates resulting from the PIPES Act.
Climate Issues
Future legislative and regulatory programs could significantly limit allowed GHG emissions or impose a cost or tax on GHG emissions. Additionally, rules that require further GHG reductions or impose additional requirements for natural gas facilities could impose additional costs.
In February 2021, the United States rejoined the Paris Agreement, an international treaty through which parties set nationally determined contributions to reduce GHG emissions, build resilience, and adapt to the impacts of climate change. Subsequently, the Biden Administration released a target for the United States to achieve a 50%-52% GHG reduction from 2005 levels by 2030, which supports the President's goals to create a carbon-free power sector by 2035 and net zero emissions economy no later than 2050. There are many pathways to reach these goals. We will carefully monitor all climate-related policy as we continue to actively implement our plans to be coal-free by 2028 and achieve our target of 90% GHG reduction, from 2005 levels, by 2030.
On July 8, 2019, the EPA published the final ACE rule, which establishes emission guidelines for states to use when developing plans to limit carbon dioxide at coal-fired electric generating units based on heat rate improvement measures. The U.S. Court of Appeals for the D.C. Circuit vacated and remanded the rule on January 19, 2021. NIPSCO will continue to monitor this matter.
ITEM 2.MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (continued)
NiSource Inc.
Off-Balance Sheet Arrangements
We, along with certain of our subsidiaries, enter into various agreements providing financial or performance assurance to third parties on behalf of certain subsidiaries. Such agreements include guarantees and stand-by letters of credit.
Refer to Note 16, “Other Commitments and Contingencies,” in the Notes to Condensed Consolidated Financial Statements (unaudited) for additional information about such arrangements.
Market Risk Disclosures
Risk is an inherent part of our businesses. The extent to which we properly and effectively identify, assess, monitor and manage each of the various types of risk involved in our businesses is critical to our profitability. We seek to identify, assess, monitor and manage, in accordance with defined policies and procedures, the following principal market risks that are involved in our businesses: commodity price risk, interest rate risk and credit risk. We manage risk through a multi-faceted process with oversight by the Risk Management Committee that requires constant communication, judgment and knowledge of specialized products and markets. Our senior management takes an active role in the risk management process and has developed policies and procedures that require specific administrative and business functions to assist in the identification, assessment and control of various risks. These may include, but are not limited to market, operational, financial, compliance and strategic risk types. In recognition of the increasingly varied and complex nature of the energy business, our risk management process, policies and procedures continue to evolve and are subject to ongoing review and modification.
Commodity Price Risk
We are exposed to commodity price risk as a result of our subsidiaries’ operations involving natural gas and power. To manage this market risk, our subsidiaries use derivatives, including commodity futures contracts, swaps, forwards and options. We do not participate in speculative energy trading activity.
Commodity price risk resulting from derivative activities at our rate-regulated subsidiaries is limited, since regulations allow recovery of prudently incurred purchased power, fuel and gas costs through the ratemaking process, including gains or losses on these derivative instruments. If states should explore additional regulatory reform, these subsidiaries may begin providing services without the benefit of the traditional ratemaking process and may be more exposed to commodity price risk.
Our subsidiaries are required to make cash margin deposits with their brokers to cover actual and potential losses in the value of outstanding exchange traded derivative contracts. The amount of these deposits, some of which are reflected in our restricted cash balance, may fluctuate significantly during periods of high volatility in the energy commodity markets.
Refer to Note 9, "Risk Management Activities," in the Notes to Condensed Consolidated Financial Statements (unaudited) for further information on our commodity price risk assets and liabilities as of June 30, 2021 or December 31, 2020.
Interest Rate Risk
We are exposed to interest rate risk as a result of changes in interest rates on borrowings under our revolving credit agreement, commercial paper program, accounts receivable programs and now-settled term loan, which have interest rates that are indexed to short-term market interest rates. Based upon average borrowings and debt obligations subject to fluctuations in short-term market interest rates, an increase (or decrease) in short-term interest rates of 100 basis points (1%) would have increased (or decreased) interest expense by $0.2 million and $1.4 million for the three and six months ended June 30, 2021, and $3.4 million and $7.7 million for the three and six months ended June 30, 2020, respectively. We are also exposed to interest rate risk as a result of changes in benchmark rates that can influence the interest rates of future debt issuances.
Refer to Note 9, "Risk Management Activities," in the Notes to Condensed Consolidated Financial Statements (unaudited) for further information on our interest rate risk assets and liabilities as of June 30, 2021 and December 31, 2020.
Credit Risk
Due to the nature of the industry, credit risk is embedded in many of our business activities. Our extension of credit is governed by a Corporate Credit Risk Policy. In addition, Risk Management Committee guidelines are in place which document management approval levels for credit limits, evaluation of creditworthiness, and credit risk mitigation efforts. Exposures to credit risks are monitored by the risk management function, which is independent of commercial operations. Credit risk arises due to the possibility that a customer, supplier or counterparty will not be able or willing to fulfill its obligations on a transaction on or before the settlement date. For derivative-related contracts, credit risk arises when counterparties are obligated to deliver or purchase defined commodity units of gas or power to us at a future date per execution of contractual terms and
ITEM 2.MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (continued)
NiSource Inc.
conditions. Exposure to credit risk is measured in terms of both current obligations and the market value of forward positions net of any posted collateral such as cash and letters of credit.
We closely monitor the financial status of our banking credit providers. We evaluate the financial status of our banking partners through the use of market-based metrics such as credit default swap pricing levels, and also through traditional credit ratings provided by major credit rating agencies.
Certain individual state regulatory commissions instituted regulatory moratoriums in connection with the COVID-19 pandemic that impacted our ability to pursue our credit risk mitigation practices for customer accounts receivable. Following the issuances of these moratoriums, certain of our regulated operations have been authorized to recognize a regulatory asset for bad debt costs above levels currently in rates. We have reinstated our common credit mitigation practices where moratoriums have expired. Refer to Note 8, "Regulatory Matters" in the Notes to Condensed Consolidated Financial Statements (unaudited) for state-specific regulatory moratoriums.
Other Information
Critical Accounting Estimates
Refer to Note 3, "Revenue Recognition," in the Notes to Condensed Consolidated Financial Statements (unaudited) for additional information about management judgment used in determining allowance for credit losses.
Refer to Note 11, "Goodwill," in the Notes to Condensed Consolidated Financial Statements (unaudited) for additional information about management judgment used in the annual goodwill impairment analysis performed as of May 1, 2021.
Refer to Note 14, "Variable Interest Entities," in the Notes to Condensed Consolidated Financial Statements (unaudited) for additional information about management judgement used in determining how to account for our variable interest entity.
Recently Issued Accounting Pronouncements
Refer to Note 2, "Recent Accounting Pronouncements," in the Notes to Condensed Consolidated Financial Statements (unaudited) for additional information about recently issued and adopted accounting pronouncements.
ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK
For a discussion regarding quantitative and qualitative disclosures about market risk see “Management’s Discussion and Analysis of Financial Condition and Results of Operations - Market Risk Disclosures.”
ITEM 4. CONTROLS AND PROCEDURES
Evaluation of Disclosure Controls and Procedures
Our chief executive officer and our chief financial officer are responsible for evaluating the effectiveness of our disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)). Our disclosure controls and procedures are designed to provide reasonable assurance that the information required to be disclosed by us in reports that we file or submit under the Exchange Act is accumulated and communicated to our management, including our chief executive officer and chief financial officer, as appropriate, to allow timely decisions regarding required disclosure and is recorded, processed, summarized and reported within the time periods specified in the rules and forms of the SEC. Based upon that evaluation, our chief executive officer and chief financial officer concluded that, as of the end of the period covered by this report, our disclosure controls and procedures were effective to provide reasonable assurance that financial information was processed, recorded and reported accurately.
Changes in Internal Controls
There have been no changes in our internal control over financial reporting during the most recently completed quarter covered by this report that has materially affected, or is reasonably likely to materially affect, our internal control over financial reporting.
For a description of our legal proceedings, see Note 16-B, "Legal Proceedings," in the Notes to Condensed Consolidated Financial Statements (unaudited).
ITEM 1A. RISK FACTORS
Please refer to the risk factors set forth in Part I, Item 1A of the Company’s Annual Report on Form 10-K for the year ended December 31, 2020, as supplemented by the risk factors set forth in Part II, Item 1A of the Company's Quarterly Report on Form 10-Q for the quarterly period ended March 31, 2021.
ITEM 2. UNREGISTERED SALES OF EQUITY SECURITIES AND USE OF PROCEEDS
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Pursuant to the requirements of the Securities Exchange Act of 1934, the Registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized.
NiSource Inc.
(Registrant)
Date:
August 4, 2021
By:
/s/ Gunnar J. Gode
Gunnar J. Gode
Vice President, Chief Accounting Officer and Controller (Principal Accounting Officer)
