ITEM 1. FINANCIAL STATEMENTS
NiSource Inc.
Condensed Statements of Consolidated Income (Loss) (unaudited)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended
June 30,
|
|
|
|
Six Months Ended
June 30,
|
|
|
|
(in millions, except per share amounts)
|
2020
|
|
2019
|
|
2020
|
|
2019
|
|
Operating Revenues
|
|
|
|
|
|
|
|
|
Customer revenues
|
$
|
932.7
|
|
|
$
|
969.2
|
|
|
$
|
2,458.6
|
|
|
$
|
2,803.7
|
|
|
Other revenues
|
30.0
|
|
|
41.2
|
|
|
109.6
|
|
|
76.5
|
|
|
Total Operating Revenues
|
962.7
|
|
|
1,010.4
|
|
|
2,568.2
|
|
|
2,880.2
|
|
|
Operating Expenses
|
|
|
|
|
|
|
|
|
Cost of sales (excluding depreciation and amortization)
|
188.4
|
|
|
253.5
|
|
|
650.8
|
|
|
933.8
|
|
|
Operation and maintenance
|
353.1
|
|
|
49.2
|
|
|
797.7
|
|
|
601.6
|
|
|
Depreciation and amortization
|
177.5
|
|
|
177.9
|
|
|
361.8
|
|
|
353.0
|
|
|
Loss on classification as held for sale
|
84.4
|
|
|
—
|
|
|
364.6
|
|
|
—
|
|
|
Loss (gain) on sale of fixed assets and impairments, net
|
(0.6)
|
|
|
(0.1)
|
|
|
(0.7)
|
|
|
0.1
|
|
|
Other taxes
|
68.2
|
|
|
66.4
|
|
|
154.1
|
|
|
154.0
|
|
|
Total Operating Expenses
|
871.0
|
|
|
546.9
|
|
|
2,328.3
|
|
|
2,042.5
|
|
|
|
|
|
|
|
|
|
|
|
Operating Income
|
91.7
|
|
|
463.5
|
|
|
239.9
|
|
|
837.7
|
|
|
Other Income (Deductions)
|
|
|
|
|
|
|
|
|
Interest expense, net
|
(97.0)
|
|
|
(94.1)
|
|
|
(189.9)
|
|
|
(189.7)
|
|
|
Other, net
|
6.5
|
|
|
(0.3)
|
|
|
11.9
|
|
|
(1.0)
|
|
|
|
|
|
|
|
|
|
|
|
Total Other Deductions, Net
|
(90.5)
|
|
|
(94.4)
|
|
|
(178.0)
|
|
|
(190.7)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Income before Income Taxes
|
1.2
|
|
|
369.1
|
|
|
61.9
|
|
|
647.0
|
|
|
Income Taxes
|
5.9
|
|
|
72.2
|
|
|
(9.0)
|
|
|
131.2
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net Income (Loss)
|
(4.7)
|
|
|
296.9
|
|
|
70.9
|
|
|
515.8
|
|
|
Preferred dividends
|
(13.8)
|
|
|
(13.8)
|
|
|
(27.6)
|
|
|
(27.6)
|
|
|
Net Income (Loss) Available to Common Shareholders
|
(18.5)
|
|
|
283.1
|
|
|
43.3
|
|
|
488.2
|
|
|
Earnings (Loss) Per Share
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Basic Earnings (Loss) Per Share
|
$
|
(0.05)
|
|
|
$
|
0.76
|
|
|
$
|
0.11
|
|
|
$
|
1.31
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Diluted Earnings (Loss) Per Share
|
$
|
(0.05)
|
|
|
$
|
0.75
|
|
|
$
|
0.11
|
|
|
$
|
1.30
|
|
|
|
|
|
|
|
|
|
|
|
Basic Average Common Shares Outstanding
|
383.5
|
|
|
373.9
|
|
|
383.3
|
|
|
373.6
|
|
|
Diluted Average Common Shares
|
383.5
|
|
|
375.2
|
|
|
384.2
|
|
|
374.9
|
|
The accompanying Notes to Condensed Consolidated Financial Statements (unaudited) are an integral part of these statements.
Table of Contents
ITEM 1. FINANCIAL STATEMENTS (continued)
NiSource Inc.
Condensed Statements of Consolidated Comprehensive Income (Loss) (unaudited)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended
June 30,
|
|
|
|
Six Months Ended
June 30,
|
|
|
|
(in millions, net of taxes)
|
2020
|
|
2019
|
|
2020
|
|
2019
|
|
Net Income (Loss)
|
$
|
(4.7)
|
|
|
$
|
296.9
|
|
|
$
|
70.9
|
|
|
$
|
515.8
|
|
|
Other comprehensive income (loss):
|
|
|
|
|
|
|
|
|
Net unrealized gain on available-for-sale debt securities(1)
|
5.7
|
|
|
2.1
|
|
|
0.3
|
|
|
4.9
|
|
|
Net unrealized gain (loss) on cash flow hedges(2)
|
2.7
|
|
|
(30.5)
|
|
|
(130.6)
|
|
|
(49.8)
|
|
|
Unrecognized pension and OPEB benefit(3)
|
0.3
|
|
|
0.4
|
|
|
1.0
|
|
|
1.3
|
|
|
Total other comprehensive income (loss)
|
8.7
|
|
|
(28.0)
|
|
|
(129.3)
|
|
|
(43.6)
|
|
|
Comprehensive Income (Loss)
|
$
|
4.0
|
|
|
$
|
268.9
|
|
|
$
|
(58.4)
|
|
|
$
|
472.2
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(1) Net unrealized gain on available-for-sale debt securities, net of $1.5 million and $0.6 million tax expense in the second quarter of 2020 and 2019, respectively, and $0.1 million and $1.3 million tax expense for the six months ended 2020 and 2019, respectively.
(2) Net unrealized gain (loss) on cash flow hedges, net of $0.9 million tax expense and $10.0 million tax benefit in the second quarter of 2020 and 2019, respectively, and $43.2 million and $16.5 million tax benefit for the six months ended 2020 and 2019, respectively.
(3) Unrecognized pension and OPEB benefit, net of $0.2 million and $0.1 million tax expense in the second quarter of 2020 and 2019, respectively, and $0.1 million tax benefit and $0.5 million tax expense for the six months ended 2020 and 2019, respectively.
The accompanying Notes to Condensed Consolidated Financial Statements (unaudited) are an integral part of these statements.
Table of Contents
ITEM 1. FINANCIAL STATEMENTS (continued)
NiSource Inc.
Condensed Consolidated Balance Sheets (unaudited)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(in millions)
|
June 30,
2020
|
|
December 31,
2019
|
|
ASSETS
|
|
|
|
|
Property, Plant and Equipment
|
|
|
|
|
Utility plant
|
$
|
20,427.1
|
|
|
$
|
24,502.6
|
|
|
Accumulated depreciation and amortization
|
(5,549.0)
|
|
|
(7,609.3)
|
|
|
Net utility plant
|
14,878.1
|
|
|
16,893.3
|
|
|
Other property, at cost, less accumulated depreciation
|
894.3
|
|
|
18.9
|
|
|
Net Property, Plant and Equipment
|
15,772.4
|
|
|
16,912.2
|
|
|
Investments and Other Assets
|
|
|
|
|
Unconsolidated affiliates
|
1.4
|
|
|
1.3
|
|
|
Available-for-sale debt securities (amortized cost of $151.4 and $150.1, allowance for credit losses of $0.8 and $0, respectively)
|
155.2
|
|
|
154.2
|
|
|
Other investments
|
72.6
|
|
|
74.7
|
|
|
Total Investments and Other Assets
|
229.2
|
|
|
230.2
|
|
|
Current Assets
|
|
|
|
|
Cash and cash equivalents
|
142.2
|
|
|
139.3
|
|
|
Restricted cash
|
11.4
|
|
|
9.1
|
|
|
Accounts receivable
|
577.1
|
|
|
876.1
|
|
|
Allowance for credit losses
|
(31.4)
|
|
|
(19.2)
|
|
|
Accounts receivable, net
|
545.7
|
|
|
856.9
|
|
|
Gas inventory
|
112.4
|
|
|
250.9
|
|
|
Materials and supplies, at average cost
|
131.8
|
|
|
120.2
|
|
|
Electric production fuel, at average cost
|
67.6
|
|
|
53.6
|
|
|
Exchange gas receivable
|
17.9
|
|
|
48.5
|
|
|
Assets held for sale
|
1,542.3
|
|
|
—
|
|
|
Regulatory assets
|
145.7
|
|
|
225.7
|
|
|
Prepayments and other
|
142.6
|
|
|
149.7
|
|
|
Total Current Assets
|
2,859.6
|
|
|
1,853.9
|
|
|
Other Assets
|
|
|
|
|
Regulatory assets
|
1,926.3
|
|
|
2,013.9
|
|
|
Goodwill
|
1,485.9
|
|
|
1,485.9
|
|
|
|
|
|
|
|
Deferred charges and other
|
163.1
|
|
|
163.7
|
|
|
Total Other Assets
|
3,575.3
|
|
|
3,663.5
|
|
|
Total Assets
|
$
|
22,436.5
|
|
|
$
|
22,659.8
|
|
The accompanying Notes to Condensed Consolidated Financial Statements (unaudited) are an integral part of these statements.
Table of Contents
ITEM 1. FINANCIAL STATEMENTS (continued)
NiSource Inc.
Condensed Consolidated Balance Sheets (unaudited) (continued)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(in millions, except share amounts)
|
June 30,
2020
|
|
December 31,
2019
|
|
CAPITALIZATION AND LIABILITIES
|
|
|
|
|
Capitalization
|
|
|
|
|
Stockholders’ Equity
|
|
|
|
|
Common stock - $0.01 par value, 600,000,000 shares authorized; 382,917,033 and 382,135,680 shares outstanding, respectively
|
$
|
3.8
|
|
|
$
|
3.8
|
|
|
Preferred stock - $0.01 par value, 20,000,000 shares authorized; 440,000 shares outstanding
|
880.0
|
|
|
880.0
|
|
|
Treasury stock
|
(99.9)
|
|
|
(99.9)
|
|
|
Additional paid-in capital
|
6,676.5
|
|
|
6,666.2
|
|
|
Retained deficit
|
(1,576.7)
|
|
|
(1,370.8)
|
|
|
Accumulated other comprehensive loss
|
(221.9)
|
|
|
(92.6)
|
|
|
Total Stockholders’ Equity
|
5,661.8
|
|
|
5,986.7
|
|
|
Long-term debt, excluding amounts due within one year
|
8,810.2
|
|
|
7,856.2
|
|
|
Total Capitalization
|
14,472.0
|
|
|
13,842.9
|
|
|
Current Liabilities
|
|
|
|
|
Current portion of long-term debt
|
15.6
|
|
|
13.4
|
|
|
Short-term borrowings
|
1,163.5
|
|
|
1,773.2
|
|
|
Accounts payable
|
402.5
|
|
|
666.0
|
|
|
Dividends payable - common stock
|
80.4
|
|
|
—
|
|
|
Dividends payable - preferred stock
|
8.1
|
|
|
—
|
|
|
Customer deposits and credits
|
163.1
|
|
|
256.4
|
|
|
Taxes accrued
|
195.7
|
|
|
231.6
|
|
|
Interest accrued
|
106.0
|
|
|
99.4
|
|
|
Risk management liabilities
|
120.0
|
|
|
12.6
|
|
|
Exchange gas payable
|
27.7
|
|
|
59.7
|
|
|
Regulatory liabilities
|
184.9
|
|
|
160.2
|
|
|
Liabilities held for sale
|
455.4
|
|
|
—
|
|
|
Legal and environmental
|
21.6
|
|
|
20.1
|
|
|
Accrued compensation and employee benefits
|
120.3
|
|
|
156.3
|
|
|
Claims accrued
|
22.4
|
|
|
165.4
|
|
|
Other accruals
|
140.5
|
|
|
131.5
|
|
|
Total Current Liabilities
|
3,227.7
|
|
|
3,745.8
|
|
|
Other Liabilities
|
|
|
|
|
Risk management liabilities
|
200.0
|
|
|
134.0
|
|
|
Deferred income taxes
|
1,477.4
|
|
|
1,485.3
|
|
|
Deferred investment tax credits
|
9.1
|
|
|
9.7
|
|
|
Accrued insurance liabilities
|
85.4
|
|
|
81.5
|
|
|
Accrued liability for postretirement and postemployment benefits
|
351.3
|
|
|
373.2
|
|
|
Regulatory liabilities
|
1,967.7
|
|
|
2,352.0
|
|
|
Asset retirement obligations
|
447.1
|
|
|
416.9
|
|
|
Other noncurrent liabilities
|
198.8
|
|
|
218.5
|
|
|
Total Other Liabilities
|
4,736.8
|
|
|
5,071.1
|
|
|
Commitments and Contingencies (Refer to Note 19, "Other Commitments and Contingencies")
|
—
|
|
|
—
|
|
|
Total Capitalization and Liabilities
|
$
|
22,436.5
|
|
|
$
|
22,659.8
|
|
The accompanying Notes to Condensed Consolidated Financial Statements (unaudited) are an integral part of these statements.
Table of Contents
ITEM 1. FINANCIAL STATEMENTS (continued)
NiSource Inc.
Condensed Statements of Consolidated Cash Flows (unaudited)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Six Months Ended June 30, (in millions)
|
2020
|
|
2019
|
|
Operating Activities
|
|
|
|
|
Net Income
|
$
|
70.9
|
|
|
$
|
515.8
|
|
|
Adjustments to Reconcile Net Income to Net Cash from Operating Activities:
|
|
|
|
|
|
|
|
|
|
Depreciation and amortization
|
361.8
|
|
|
353.0
|
|
|
Deferred income taxes and investment tax credits
|
(11.4)
|
|
|
126.5
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Loss on classification as held for sale
|
364.6
|
|
|
—
|
|
|
Other adjustments
|
7.7
|
|
|
13.6
|
|
|
Changes in Assets and Liabilities:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Components of working capital
|
(75.9)
|
|
|
(9.0)
|
|
|
Regulatory assets/liabilities
|
17.0
|
|
|
(40.9)
|
|
|
|
|
|
|
|
|
|
|
|
|
Deferred charges and other noncurrent assets
|
(17.4)
|
|
|
(68.4)
|
|
|
Other noncurrent liabilities
|
(9.6)
|
|
|
35.6
|
|
|
|
|
|
|
|
|
|
|
|
|
Net Cash Flows from Operating Activities
|
707.7
|
|
|
926.2
|
|
|
Investing Activities
|
|
|
|
|
Capital expenditures
|
(819.3)
|
|
|
(843.5)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Cost of removal
|
(66.7)
|
|
|
(55.7)
|
|
|
|
|
|
|
|
|
|
|
|
|
Other investing activities
|
(0.6)
|
|
|
1.2
|
|
|
|
|
|
|
|
|
|
|
|
|
Net Cash Flows used for Investing Activities
|
(886.6)
|
|
|
(898.0)
|
|
|
Financing Activities
|
|
|
|
|
|
|
|
|
|
Issuance of long-term debt
|
1,000.0
|
|
|
—
|
|
|
Repayments of long-term debt and finance lease obligations
|
(7.8)
|
|
|
(46.0)
|
|
|
Issuance of short-term debt (maturity > 90 days)
|
1,350.0
|
|
|
500.0
|
|
|
Repayment of short-term debt (maturity > 90 days)
|
(1,350.0)
|
|
|
(350.0)
|
|
|
Change in short-term borrowings, net (maturity ≤ 90 days)
|
(609.7)
|
|
|
(46.2)
|
|
|
Issuance of common stock, net of issuance costs
|
7.5
|
|
|
7.1
|
|
|
|
|
|
|
Equity costs, premiums and other debt related costs
|
(17.6)
|
|
|
(4.2)
|
|
|
|
|
|
|
|
Dividends paid - common stock
|
(160.7)
|
|
|
(149.1)
|
|
|
Dividends paid - preferred stock
|
(27.6)
|
|
|
(28.5)
|
|
|
|
|
|
|
|
|
|
|
|
|
Net Cash Flows from (used for) Financing Activities
|
184.1
|
|
|
(116.9)
|
|
|
Change in cash, cash equivalents and restricted cash
|
5.2
|
|
|
(88.7)
|
|
|
|
|
|
|
|
|
|
|
|
|
Cash, cash equivalents and restricted cash at beginning of period
|
148.4
|
|
|
121.1
|
|
|
Cash, Cash Equivalents and Restricted Cash at End of Period
|
$
|
153.6
|
|
|
$
|
32.4
|
|
Supplemental Disclosures of Cash Flow Information
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Six Months Ended June 30, (in millions)
|
2020
|
|
2019
|
|
Non-cash transactions:
|
|
|
|
|
Capital expenditures included in current liabilities
|
$
|
167.7
|
|
|
$
|
169.3
|
|
|
Dividends declared but not paid
|
88.5
|
|
|
82.7
|
|
|
|
|
|
|
|
Assets recorded for asset retirement obligations
|
$
|
70.3
|
|
|
$
|
12.8
|
|
The accompanying Notes to Condensed Consolidated Financial Statements (unaudited) are an integral part of these statements.
Table of Contents
ITEM 1. FINANCIAL STATEMENTS (continued)
NiSource Inc.
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
|
|
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
|
|
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.
Table of Contents
ITEM 1. FINANCIAL STATEMENTS (continued)
NiSource Inc.
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
|
|
Total
|
|
Balance as of April 1, 2019
|
$
|
3.8
|
|
|
$
|
880.0
|
|
|
$
|
(99.9)
|
|
|
$
|
6,406.5
|
|
|
$
|
(1,358.0)
|
|
|
$
|
(52.8)
|
|
|
$
|
5,779.6
|
|
|
Comprehensive Income:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
296.9
|
|
|
—
|
|
|
296.9
|
|
|
Other comprehensive loss, net of tax
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
(28.0)
|
|
|
(28.0)
|
|
|
Dividends:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Common stock ($0.20 per share)
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
(74.7)
|
|
|
—
|
|
|
(74.7)
|
|
|
Preferred stock (See Note 5)
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
(8.2)
|
|
|
—
|
|
|
(8.2)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Stock issuances:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Employee stock purchase plan
|
—
|
|
|
—
|
|
|
—
|
|
|
1.4
|
|
|
—
|
|
|
—
|
|
|
1.4
|
|
|
Long-term incentive plan
|
—
|
|
|
—
|
|
|
—
|
|
|
4.8
|
|
|
—
|
|
|
—
|
|
|
4.8
|
|
|
401(k) and profit sharing
|
—
|
|
|
—
|
|
|
—
|
|
|
4.4
|
|
|
—
|
|
|
—
|
|
|
4.4
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Balance as of June 30, 2019
|
$
|
3.8
|
|
|
$
|
880.0
|
|
|
$
|
(99.9)
|
|
|
$
|
6,417.1
|
|
|
$
|
(1,144.0)
|
|
|
$
|
(80.8)
|
|
|
$
|
5,976.2
|
|
|
(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
|
|
Total
|
|
Balance as of January 1, 2019
|
$
|
3.8
|
|
|
$
|
880.0
|
|
|
$
|
(99.9)
|
|
|
$
|
6,403.5
|
|
|
$
|
(1,399.3)
|
|
|
$
|
(37.2)
|
|
|
$
|
5,750.9
|
|
|
Comprehensive Income:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
515.8
|
|
|
—
|
|
|
515.8
|
|
|
Other comprehensive loss, net of tax
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
(43.6)
|
|
|
(43.6)
|
|
|
Dividends:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Common stock ($0.60 per share)
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
(223.8)
|
|
|
—
|
|
|
(223.8)
|
|
|
Preferred stock (See Note 5)
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
(36.7)
|
|
|
—
|
|
|
(36.7)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Stock issuances:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Employee stock purchase plan
|
—
|
|
|
—
|
|
|
—
|
|
|
2.7
|
|
|
—
|
|
|
—
|
|
|
2.7
|
|
|
Long-term incentive plan
|
—
|
|
|
—
|
|
|
—
|
|
|
2.1
|
|
|
—
|
|
|
—
|
|
|
2.1
|
|
|
401(k) and profit sharing
|
—
|
|
|
—
|
|
|
—
|
|
|
8.8
|
|
|
—
|
|
|
—
|
|
|
8.8
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Balance as of June 30, 2019
|
$
|
3.8
|
|
|
$
|
880.0
|
|
|
$
|
(99.9)
|
|
|
$
|
6,417.1
|
|
|
$
|
(1,144.0)
|
|
|
$
|
(80.8)
|
|
|
$
|
5,976.2
|
|
(1)Series A and Series B shares have an aggregate liquidation preference of $400M and $500M, respectively. See Note 5, "Equity" for additional information.
Table of Contents
ITEM 1. FINANCIAL STATEMENTS (continued)
NiSource Inc.
Condensed Statements of Consolidated Equity (unaudited) (continued)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Preferred
|
|
Common
|
|
|
|
|
|
Shares (in thousands)
|
Shares
|
|
Shares
|
|
Treasury
|
|
Outstanding
|
|
Balance as of April 1, 2020
|
440
|
|
|
386,657
|
|
|
(3,963)
|
|
|
382,694
|
|
|
Issued:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Employee stock purchase plan
|
—
|
|
|
60
|
|
|
—
|
|
|
60
|
|
|
Long-term incentive plan
|
—
|
|
|
32
|
|
|
—
|
|
|
32
|
|
|
401(k) and profit sharing
|
—
|
|
|
131
|
|
|
—
|
|
|
131
|
|
|
|
|
|
|
|
|
|
|
|
Balance as of June 30, 2020
|
440
|
|
|
386,880
|
|
|
(3,963)
|
|
|
382,917
|
|
|
|
|
|
|
|
|
|
|
|
|
Preferred
|
|
Common
|
|
|
|
|
|
Shares (in thousands)
|
Shares
|
|
Shares
|
|
Treasury
|
|
Outstanding
|
|
Balance as of January 1, 2020
|
440
|
|
|
386,099
|
|
|
(3,963)
|
|
|
382,136
|
|
|
Issued:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Employee stock purchase plan
|
—
|
|
|
106
|
|
|
—
|
|
|
106
|
|
|
Long-term incentive plan
|
—
|
|
|
379
|
|
|
—
|
|
|
379
|
|
|
401(k) and profit sharing
|
—
|
|
|
296
|
|
|
—
|
|
|
296
|
|
|
|
|
|
|
|
|
|
|
|
Balance as of June 30, 2020
|
440
|
|
|
386,880
|
|
|
(3,963)
|
|
|
382,917
|
|
|
|
|
|
|
|
|
|
|
|
|
Preferred
|
|
Common
|
|
|
|
|
|
Shares (in thousands)
|
Shares
|
|
Shares
|
|
Treasury
|
|
Outstanding
|
|
Balance as of April 1, 2019
|
440
|
|
|
376,966
|
|
|
(3,963)
|
|
|
373,003
|
|
|
Issued:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Employee stock purchase plan
|
—
|
|
|
52
|
|
|
—
|
|
|
52
|
|
|
Long-term incentive plan
|
—
|
|
|
38
|
|
|
—
|
|
|
38
|
|
|
401(k) and profit sharing
|
—
|
|
|
156
|
|
|
—
|
|
|
156
|
|
|
|
|
|
|
|
|
|
|
|
Balance as of June 30, 2019
|
440
|
|
|
377,212
|
|
|
(3,963)
|
|
|
373,249
|
|
|
|
|
|
|
|
|
|
|
|
|
Preferred
|
|
Common
|
|
|
|
|
|
Shares (in thousands)
|
Shares
|
|
Shares
|
|
Treasury
|
|
Outstanding
|
|
Balance as of January 1, 2019
|
420
|
|
|
376,326
|
|
|
(3,963)
|
|
|
372,363
|
|
|
Issued:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Preferred stock
|
20
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
Employee stock purchase plan
|
—
|
|
|
102
|
|
|
—
|
|
|
102
|
|
|
Long-term incentive plan
|
—
|
|
|
464
|
|
|
—
|
|
|
464
|
|
|
401(k) and profit sharing
|
—
|
|
|
320
|
|
|
—
|
|
|
320
|
|
|
|
|
|
|
|
|
|
|
|
Balance as of June 30, 2019
|
440
|
|
|
377,212
|
|
|
(3,963)
|
|
|
373,249
|
|
Table of Contents
ITEM 1. FINANCIAL STATEMENTS (continued)
NiSource Inc.
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 contain our accounts and that of our majority-owned or controlled subsidiaries.
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, 2019. 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.
During the first quarter of 2020, the United States and countries around the globe were impacted by the outbreak of the novel coronavirus (COVID-19). On March 11, 2020, the World Health Organization (WHO) declared the outbreak of COVID-19 to be a global pandemic. In response to this declaration and the rapid spread of COVID-19 within the United States, federal, state and local governments throughout the country have imposed varying degrees of restrictions on social and commercial activity to promote social distancing in an effort to slow the spread of the illness. These measures have had and continue to have a significant adverse impact upon many sectors of the economy.
COVID-19 has impacted our results of operation in the first half of 2020. As a result of COVID-19, we have experienced, and expect to continue to experience, lower commercial and industrial demand for both the Electric Operations and the Gas Distribution Operations segments and higher residential demand for both the Electric Operations and the Gas Distribution Operations segments. In addition, we have incurred incremental costs for COVID-19 related services and supplies, as well as higher bad debt expense. Due to the uncertainty and evolving situation, we will 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. See Note 3, “Revenue Recognition,” Note 10, “Regulatory Matters,” Note 14, “Goodwill,” and Note 15, “Income Taxes,” for information on COVID-19.
Table of Contents
ITEM 1. FINANCIAL STATEMENTS (continued)
NiSource Inc.
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 2018-14, Compensation—Retirement Benefits—Defined Benefit Plans—General (Subtopic 715-20): Disclosure Framework—Changes to the Disclosure Requirements for Defined Benefit Plans
|
This pronouncement modifies the disclosure requirements for defined benefit pension or other postretirement benefit plans. The guidance removes disclosures that are no longer considered cost beneficial, clarifies the specific requirements of disclosures and adds disclosure requirements identified as relevant. The modifications affect annual period disclosures and must be applied on a retrospective basis to all periods presented.
|
Annual periods ending after December 15, 2020. Early adoption is permitted.
|
We are currently in discussions with our third-party specialist to evaluate the effects of this pronouncement on our Notes to Condensed Consolidated Financial Statements (unaudited). These discussions include, but are not limited to, understanding new information to be provided by the specialists in order to meet disclosure requirements. We expect to adopt this ASU on its effective date.
|
|
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.
|
Annual periods beginning after December 15, 2020 Early adoption is permitted.
|
The most relevant amendment requires that an entity recognize a franchise tax (or similar tax) that is partially based on income as an income-based tax and account for any incremental amount incurred as a non-income-based tax. For us, these taxes include the Massachusetts excise tax that is currently recorded as non-income based taxes. Consequently, we do not expect an impact on our Condensed Consolidated Financial Statements (unaudited) and Notes to Condensed Consolidated Financial Statements (unaudited). We continue to monitor the guidance as it relates to new activity or transactions that could impact our Condensed Consolidated Financial Statements (unaudited) and Notes to Condensed Consolidated Financial Statements (unaudited). We expect to adopt this ASU on its effective date.
|
|
ASU 2020-04, Reference Rate Reform (Topic 848): Facilitation of the Effects of Reference Rate Reform on Financial Statements
|
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 though December 31, 2022.
|
We are currently evaluating 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, 2020, we have not applied any expedients and options available under this ASU.
|
Table of Contents
ITEM 1. FINANCIAL STATEMENTS (continued)
NiSource Inc.
Notes to Condensed Consolidated Financial Statements (unaudited) (continued)
Recently Adopted Accounting Pronouncements
|
|
|
|
|
|
|
|
Standard
|
Adoption
|
|
ASU 2019-04, Codification Improvements to Topic 326, Financial Instruments-Credit Losses, Topic 815, Derivatives and Hedging, and Topic 825, Financial Instruments
|
In June 2016, the FASB issued ASU 2016-13, Measurement of Credit Losses on Financial Instruments (ASC 326). ASC 326 revised the GAAP guidance on the impairment of most financial assets and certain other instruments that are not measured at fair value through net income. ASC 326 introduces the current expected credit loss (CECL) model that is based on expected losses for instruments measured at amortized cost rather than incurred losses. It also requires entities to record an allowance for available-for-sale debt securities rather than impair the carrying amount of the securities. Subsequent improvements to the estimated credit losses of available-for-sale debt securities will be recognized immediately in earnings, instead of over-time as they would under historic guidance. In 2019, the FASB issued ASU 2019-04, Codification Improvements to Topic 326, Financial Instruments-Credit Losses, Topic 815, Derivative and Hedging, and Topic 825, Financial Instruments. This pronouncement clarified and improved certain areas of guidance related to the recently issued standards on credit losses, hedging, and recognition and measurement.
We adopted ASC 326 effective January 1, 2020, using a modified retrospective method. Adoption of this standard did not have material impact on our Condensed Consolidated Financial Statements (unaudited). No adjustments were made to the January 1, 2020 opening balances as a result of this adoption. As required under the modified retrospective method of adoption, results for the reporting periods beginning after January 1, 2020 are presented under ASC 326, while prior period amounts are not adjusted.
See Note 3, "Revenue Recognition," and Note 11, "Fair Value," for our discussion of the implementing these standards.
|
|
ASU 2016-13, Financial Instruments-Credit Losses (Topic 326)
|
|
3. Revenue Recognition
Revenue Disaggregation and Reconciliation. We disaggregate revenue from contracts with customers based upon reportable segment, as well as by customer class. As our revenues are primarily earned over a period of time and we do not earn a material amount of revenues at a point in time, revenues are not disaggregated as such below. The Gas Distribution Operations segment provides natural gas service and transportation for residential, commercial and industrial customers in Ohio, Pennsylvania, Virginia, Kentucky, Maryland, Indiana and Massachusetts. The Electric Operations segment provides electric service in 20 counties in the northern part of Indiana.
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, 2020 and June 30, 2019:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
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 22, "Business Segment Information," for discussion of intersegment revenues.
Table of Contents
ITEM 1. FINANCIAL STATEMENTS (continued)
NiSource Inc.
Notes to Condensed Consolidated Financial Statements (unaudited) (continued)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended June 30, 2019 (in millions)
|
Gas Distribution Operations
|
|
Electric Operations
|
|
Corporate and Other
|
|
Total
|
|
Customer Revenues(1)
|
|
|
|
|
|
|
|
|
Residential
|
$
|
375.0
|
|
|
$
|
105.9
|
|
|
$
|
—
|
|
|
$
|
480.9
|
|
|
Commercial
|
121.8
|
|
|
115.1
|
|
|
—
|
|
|
236.9
|
|
|
Industrial
|
52.9
|
|
|
155.8
|
|
|
—
|
|
|
208.7
|
|
|
Off-system
|
23.4
|
|
|
—
|
|
|
—
|
|
|
23.4
|
|
|
Miscellaneous
|
12.4
|
|
|
6.7
|
|
|
0.2
|
|
|
19.3
|
|
|
Total Customer Revenues
|
$
|
585.5
|
|
|
$
|
383.5
|
|
|
$
|
0.2
|
|
|
$
|
969.2
|
|
|
Other Revenues
|
18.3
|
|
|
22.9
|
|
|
—
|
|
|
41.2
|
|
|
Total Operating Revenues
|
$
|
603.8
|
|
|
$
|
406.4
|
|
|
$
|
0.2
|
|
|
$
|
1,010.4
|
|
|
(1) Customer revenue amounts exclude intersegment revenues. See Note 22, "Business Segment Information," for discussion of intersegment revenues.
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
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 22, "Business Segment Information," for discussion of intersegment revenues.
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Six Months Ended June 30, 2019 (in millions)
|
Gas Distribution Operations
|
|
Electric Operations
|
|
Corporate and Other
|
|
Total
|
|
Customer Revenues(1)
|
|
|
|
|
|
|
|
|
Residential
|
$
|
1,350.3
|
|
|
$
|
224.7
|
|
|
$
|
—
|
|
|
$
|
1,575
|
|
|
Commercial
|
452.3
|
|
|
234.4
|
|
|
—
|
|
|
686.7
|
|
|
Industrial
|
135.8
|
|
|
319.1
|
|
|
—
|
|
|
454.9
|
|
|
Off-system
|
43.5
|
|
|
—
|
|
|
—
|
|
|
43.5
|
|
|
Miscellaneous
|
29.6
|
|
|
13.6
|
|
|
0.4
|
|
|
43.6
|
|
|
Total Customer Revenues
|
$
|
2,011.5
|
|
|
$
|
791.8
|
|
|
$
|
0.4
|
|
|
$
|
2,803.7
|
|
|
Other Revenues
|
31.1
|
|
|
45.4
|
|
|
—
|
|
|
76.5
|
|
|
Total Operating Revenues
|
$
|
2,042.6
|
|
|
$
|
837.2
|
|
|
$
|
0.4
|
|
|
$
|
2,880.2
|
|
|
(1) Customer revenue amounts exclude intersegment revenues. See Note 22, "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. The opening and closing balances of customer receivables for the six months ended June 30, 2020 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.
Table of Contents
ITEM 1. FINANCIAL STATEMENTS (continued)
NiSource Inc.
Notes to Condensed Consolidated Financial Statements (unaudited) (continued)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(in millions)
|
Customer Accounts Receivable, Billed (less reserve)
|
|
Customer Accounts Receivable, Unbilled (less reserve)
|
|
|
|
Balance as of December 31, 2019
|
$
|
466.6
|
|
|
$
|
346.6
|
|
|
|
|
Balance as of June 30, 2020
|
326.6
|
|
|
187.9
|
|
|
|
|
Decrease
|
$
|
(140.0)
|
|
|
$
|
(158.7)
|
|
|
|
Utility revenues are billed to customers monthly on a cycle basis. We generally expect that substantially all customer accounts receivable will be collected within the month following customer billing, as this revenue consists primarily of monthly, tariff-based billings for service and usage. We maintain common utility credit risk mitigation practices, including requiring deposits and actively pursuing collection of past due amounts. Although individual state regulatory commissions have instituted regulatory moratoriums in connection with COVID-19 that impact our ability to pursue our credit risk mitigation practices, we believe this to be temporary, and we expect to reinstate our common credit mitigation practices upon expiration of the state specific moratoriums. 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. In addition, in connection with COVID-19, certain of our regulated operations have been authorized to recognize a regulatory asset for bad debt costs above levels currently in rates (see Note 10, "Regulatory Matters," for additional information). It is probable that substantially all of the consideration to which we are entitled from customers will be collected upon satisfaction of performance obligations.
Allowance for Credit Losses. We adopted ASC 326 effective January 1, 2020. See "Recently Adopted Accounting Pronouncements" in Note 2, "Recent Accounting Pronouncements," for more information about ASC 326.
Each of our business segments pool their customer accounts receivables based on similar risk characteristics, such as customer type, geography, payment terms, and related macro-economic risks. Expected credit loss exposure is evaluated separately for each of our accounts receivable pools. 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, gas consumption trends, revenue projections, actual charge-offs data, recoveries data, shut-off orders executed data, 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 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 general economic conditions.
Table of Contents
ITEM 1. FINANCIAL STATEMENTS (continued)
NiSource Inc.
Notes to Condensed Consolidated Financial Statements (unaudited) (continued)
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 for the three and six months ended June 30, 2020 are presented in the tables below:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended June 30, 2020 (in millions)
|
Gas Distribution Operations
|
|
Electric Operations
|
|
Corporate and Other
|
|
Total
|
|
Beginning balance
|
$
|
15.9
|
|
|
$
|
3.6
|
|
|
$
|
0.8
|
|
|
$
|
20.3
|
|
|
Current period provisions
|
13.3
|
|
|
2.9
|
|
|
—
|
|
|
16.2
|
|
|
Write-offs charged against allowance
|
(6.9)
|
|
|
(1.5)
|
|
|
—
|
|
|
(8.4)
|
|
|
Recoveries of amounts previously written off
|
3.1
|
|
|
0.2
|
|
|
—
|
|
|
3.3
|
|
|
Ending balance of the allowance for credit losses
|
$
|
25.4
|
|
|
$
|
5.2
|
|
|
$
|
0.8
|
|
|
$
|
31.4
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Six Months Ended June 30, 2020 (in millions)
|
Gas Distribution Operations
|
|
Electric Operations
|
|
Corporate and Other
|
|
Total
|
|
Beginning balance(1)
|
9.1
|
|
|
3.1
|
|
|
0.8
|
|
|
13.0
|
|
|
Current period provisions
|
22.4
|
|
|
4.4
|
|
|
—
|
|
|
26.8
|
|
|
Write-offs charged against allowance
|
(13.8)
|
|
|
(2.5)
|
|
|
—
|
|
|
(16.3)
|
|
|
Recoveries of amounts previously written off
|
7.7
|
|
|
0.2
|
|
|
—
|
|
|
7.9
|
|
|
Ending balance of the allowance for credit losses
|
25.4
|
|
|
5.2
|
|
|
0.8
|
|
|
31.4
|
|
|
(1)Total beginning balance differs from that presented in the Condensed Statements of Consolidated Balance Sheet (unaudited) as it excludes Columbia of Massachusetts. Columbia of Massachusetts' customer receivables and related allowance for credit losses are classified as held for sale at June 30, 2020.
|
|
|
|
|
|
|
|
As of June 30, 2020, we have also evaluated the adequacy of our allowance for credit losses in light of the suspension of shut-offs for nonpayment due to COVID-19 and the economic downturn. Our evaluation included an analysis of customer payment trends in 2020, economic conditions, receivables aging, and considerations of past economic downturns and corresponding allowance for credit losses and customer account write-offs. In addition, we considered impacts of governmental COVID-19 relief programs, the expansion of unemployment benefits initiatives, and flexible payment plans being offered to customers impacted or experiencing hardship as a result of COVID-19, which 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, 2020 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 as additional information becomes available.
Table of Contents
ITEM 1. FINANCIAL STATEMENTS (continued)
NiSource Inc.
Notes to Condensed Consolidated Financial Statements (unaudited) (continued)
4. Earnings Per Share
Basic EPS is computed by dividing net income available to common shareholders by the weighted-average number of shares of common stock outstanding for the period. The weighted-average shares outstanding for diluted EPS includes the incremental effects of the various long-term incentive compensation plans and forward agreements when the impact would be dilutive (See Note 5 "Equity"). The computation of diluted average common shares for the three months ended June 30, 2020 is not presented as we had a net loss on the Condensed Statements of Consolidated Income (Loss) (unaudited) during the period, and any incremental shares would have had an anti-dilutive impact on EPS. The computation of diluted average common shares is as follows:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended
|
|
Six Months Ended
|
|
|
|
|
|
|
June 30,
|
|
June 30,
|
|
|
|
(in thousands)
|
|
|
2019
|
|
2020
|
|
2019
|
|
Denominator
|
|
|
|
|
|
|
|
|
Basic average common shares outstanding
|
|
|
373,898
|
|
|
383,304
|
|
|
373,628
|
|
|
Dilutive potential common shares:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Shares contingently issuable under employee stock plans
|
|
|
800
|
|
|
719
|
|
|
930
|
|
|
Shares restricted under employee stock plans
|
|
|
136
|
|
|
192
|
|
|
135
|
|
|
Forward Agreements
|
|
|
398
|
|
|
—
|
|
|
252
|
|
|
Diluted Average Common Shares
|
|
|
375,232
|
|
|
384,215
|
|
|
374,945
|
|
5. Equity
Common Stock. As of June 30, 2020, we had 600,000,000 shares of common stock authorized for issuance, of which 382,917,033 shares were outstanding.
ATM Program. On November 1, 2018, we entered into five separate equity distribution agreements pursuant to which we were able to sell up to an aggregate of $500.0 million of our common stock. Four of these agreements were then amended on August 1, 2019, and one was terminated. Pursuant to the four agreements, as amended, we may sell, from time to time, up to an aggregate of $434.4 million of our common stock.
As of June 30, 2020, the ATM program had approximately $200.7 million of equity available for issuance. The program expires on December 31, 2020. We did not have any activity under the ATM program for the three and six months ended June 30, 2020.
Preferred Stock. As of June 30, 2020, we had 20,000,000 shares of preferred stock authorized for issuance, of which 440,000 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,
|
|
|
|
|
2020
|
|
2019
|
|
2020
|
|
2019
|
|
2020
|
|
2019
|
|
(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
|
|
|
1,268.40
|
|
|
$
|
486.1
|
|
|
$
|
486.1
|
|
Table of Contents
ITEM 1. FINANCIAL STATEMENTS (continued)
NiSource Inc.
Notes to Condensed Consolidated Financial Statements (unaudited) (continued)
In addition, 20,000 shares of Series B–1 Preferred Stock, par value $0.01 per share, were outstanding as of June 30, 2020. 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, 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.
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 $19.4 million and zero as of June 30, 2020 and December 31, 2019, respectively, for certain gas distribution companies recorded within “Prepayments and other,” on the Condensed Consolidated Balance Sheets (unaudited).
7. Assets and Liabilities Held For Sale
On February 26, 2020, NiSource and Columbia of Massachusetts entered into an Asset Purchase Agreement with Eversource. Upon the terms and subject to the conditions set forth in the Asset Purchase Agreement, NiSource and Columbia of Massachusetts agreed to sell to Eversource, with certain additions and exceptions: (1) substantially all of the assets of Columbia of Massachusetts and (2) all of the assets held by any of Columbia of Massachusetts’ affiliates that primarily relate to the Massachusetts Business, and Eversource agreed to assume certain liabilities of Columbia of Massachusetts and its affiliates. The liabilities assumed by Eversource under the Asset Purchase Agreement do not include, among others, any liabilities arising out of the Greater Lawrence Incident or liabilities of Columbia of Massachusetts or its affiliates pursuant to civil claims for injury of persons or damage to property to the extent such injury or damage occurs prior to the closing in connection with the Massachusetts Business. The Asset Purchase Agreement provides for a purchase price of $1,100 million in cash, subject to adjustment based on Columbia of Massachusetts’ net working capital as of the closing.
On July 2, 2020, NiSource, Columbia of Massachusetts, Eversource and Eversource Gas Company of Massachusetts, a wholly-owned subsidiary of Eversource (“EGMA”), filed with the Massachusetts DPU a joint petition for the approval of the purchase and sale of the Massachusetts Business and a proposed multi-year rate plan. Additionally, the petition seeks approval of a settlement agreement executed on July 2, 2020 (the “Settlement Agreement”) among, NiSource, Columbia of Massachusetts, Eversource, EGMA, the Massachusetts Attorney General’s Office ("Massachusetts AGO"), the Massachusetts Department of Energy Resources ("DOER"), and the Low-Income Weatherization and Fuel Assistance Program Network. If approved as filed, the Settlement Agreement would provide final resolution or termination of proceedings before certain governmental bodies, as outlined in the Asset Purchase Agreement closing conditions. Under the terms of the Settlement Agreement, at the closing of the sale to Eversource, NiSource will make a payment in lieu of penalties in full settlement of all of the pending and potential claims, lawsuits, investigations or proceedings settled by and released by the Settlement Agreement in the amount of $56.0 million. This payment, which will be withheld from the proceeds received from Eversource, will be used to create an Energy Relief Fund that will benefit customers of the Massachusetts Business. The Settlement Agreement is conditioned on its approval in full by the Massachusetts DPU no later than September 30, 2020. See Note 19-B, "Legal Proceedings," for details about the joint petition and Settlement Agreement.
As of June 30, 2020, the Massachusetts Business meets the requirements under GAAP to be classified as held for sale, and the assets and liabilities of the Massachusetts Business are measured at fair value, less costs to sell. Our estimated total pre-tax loss for the three and six months ended June 30, 2020 is $84.4 million and $364.6 million, respectively, based on June 30, 2020 asset and liability balances, estimated net working capital and estimated transaction costs, including the $56.0 million payment in lieu of penalties described above. This estimated pre-tax loss is presented as Loss on Classification as Held for Sale on the Condensed Statements of Consolidated Income (Loss) (unaudited) and is subject to change based on estimated transaction costs, the net working capital adjustment, and asset and liability balances at each measurement date leading up to the closing date. The final pre-tax loss on the transaction will be determined as of the closing date. The sale is targeted to close by the end of the third quarter or shortly thereafter, subject to closing conditions.
Table of Contents
ITEM 1. FINANCIAL STATEMENTS (continued)
NiSource Inc.
Notes to Condensed Consolidated Financial Statements (unaudited) (continued)
The Massachusetts Business had the following pretax income (loss) for the three and six months ended June 30, 2020 and 2019:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended
June 30,
|
|
|
|
Six Months Ended
June 30,
|
|
|
|
(in millions)
|
|
2020
|
|
2019
|
|
2020
|
|
2019
|
|
Pretax Income (Loss)
|
|
($92.6)
|
|
$319.4
|
|
($328.8)
|
|
$238.7
|
The pretax income (loss) amounts exclude allocated executive compensation expense and interest expense for intercompany and external debt that will not be assumed by Eversource or required to be repaid at closing. The pretax income (loss) amounts for the three and six months ended June 30, 2020 and 2019 include costs directly related to the Greater Lawrence Incident. In addition, the pretax loss amounts for the three and six months ended June 30, 2020 include the Loss on Classification as Held for Sale. The major classes of assets and liabilities classified as held for sale on the Condensed Consolidated Balance Sheets (unaudited) at June 30, 2020 were:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(in millions)
|
|
|
|
|
|
|
|
|
|
|
Assets Held for Sale
|
Net Property, Plant and Equipment
|
|
Total Current Assets
|
|
Total Other Assets
|
|
Loss on Classification as Held for Sale(1)
|
|
Total Assets Held for Sale
|
|
Gas Distribution Operations
|
1,669.1
|
|
|
140.6
|
|
|
90.3
|
|
|
(357.7)
|
|
|
1,542.3
|
|
|
Liabilities Held for Sale
|
Long-term Debt, Excluding Amounts Due Within One Year
|
|
|
|
Total Current Liabilities
|
|
Total Other Liabilities
|
|
Total Liabilities Held for Sale
|
|
Gas Distribution Operations
|
42.0
|
|
|
|
|
61.3
|
|
|
352.1
|
|
|
455.4
|
|
(1) Amount differs from that presented in the Condensed Statements of Consolidated Income (Loss) (unaudited) due to cash already paid for certain transaction costs.
8. Property, Plant and Equipment
In the second quarter of 2020, we received approval from MISO to retire the R.M. Schahfer Generating Station (Units 14, 15, 17 and 18) in 2023. As a result of this approval, we have reclassified $876.0 million in net book value of certain plant and equipment for the R.M. Schahfer Generating Station units from “Net utility plant” to “Other Property, at cost, less accumulated depreciation” on the Condensed Consolidated Balance Sheets (unaudited). The amount of plant and equipment reclassified to other property is based on current estimates of the plant and equipment that will not be utilized at retirement in 2023. As more information about plant and equipment that can be utilized beyond 2023 becomes available, additional amounts may be reclassified to other property. Depreciation expense will continue to be recorded at the composite depreciation rate approved by the IURC. See Note 19-D, "Other Matters," for additional information.
9. Asset Retirement Obligations
During 2020, we made revisions to the estimated costs associated with refining the CCR compliance plan. The CCR rule requires the continued collection of data over time to determine the specific compliance solution. The change in estimated costs resulted in an increase to the asset retirement obligation liability of $70.3 million that was recorded in 2020. See Note 19-C, "Environmental Matters," for additional information on CCRs.
10. Regulatory 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 the subject of trackers generally result in a corresponding increase in operating revenues and, therefore, have essentially no impact on total operating income results.
Certain costs of our operating companies are significant, recurring in nature and generally outside the control of the operating companies. Some states allow the recovery of such costs through cost tracking mechanisms. Such tracking mechanisms allow for abbreviated regulatory proceedings in order for the operating companies to implement charges and recover appropriate costs. Tracking mechanisms allow for more timely recovery of such costs as compared with more traditional cost recovery mechanisms. Examples of such mechanisms include GCR adjustment mechanisms, tax riders, bad debt recovery mechanisms,
Table of Contents
ITEM 1. FINANCIAL STATEMENTS (continued)
NiSource Inc.
Notes to Condensed Consolidated Financial Statements (unaudited) (continued)
electric energy efficiency programs, MISO non-fuel costs and revenues, resource capacity charges, federally mandated costs and environmental-related costs.
A portion of the Gas Distribution revenue is related to the recovery of gas costs, the review and recovery of which occurs through standard regulatory proceedings. All states in our operating area require periodic review of actual gas procurement activity to determine prudence and to permit the recovery of prudently incurred costs related to the supply of gas for customers. Our distribution companies have historically been found prudent in the procurement of gas supplies to serve customers.
A portion of the Electric Operations revenue is related to the recovery of fuel costs to generate power and the fuel costs related to purchased power. These costs are recovered through a FAC, a quarterly regulatory proceeding in Indiana.
Infrastructure Replacement and Federally-Mandated Compliance Programs
All of our operating utility companies have completed rate proceedings involving infrastructure replacement or enhancement, and have embarked upon initiatives to replace significant portions of their operating systems that are nearing the end of their useful lives. Each company's approach to cost recovery is unique, given the different laws, regulations and precedent that exist in each jurisdiction.
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
|
Filed
|
Status
|
Rates
Effective
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Columbia of Ohio
|
IRP - 2020
|
32.9
|
|
234.4
|
|
1/19-12/19
|
February 28, 2020
|
Approved
April 22, 2020
|
May 2020
|
|
|
|
|
|
|
|
|
|
|
Columbia of Ohio
|
CEP - 2019
|
15.0
|
|
121.7
|
|
1/18-12/18
|
February 28, 2019
|
Approved
August 28, 2019
|
September 2019
|
|
Columbia of Ohio
|
CEP - 2020
|
18.0
|
|
185.1
|
|
1/19-12/19
|
February 28, 2020
|
Order Expected August 2020
|
September 2020
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
NIPSCO - Gas
|
TDSIC 10(1)
|
1.6
|
|
12.4
|
|
7/18-4/19
|
June 25, 2019
|
Approved
October 16, 2019
|
November 2019
|
|
NIPSCO - Gas
|
TDSIC 11(2)
|
(1.7)
|
|
38.7
|
|
5/19-12/19
|
February 25, 2020
|
Approved
June 24, 2020
|
July 2020
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
NIPSCO - Gas
|
FMCA 3(3)
|
0.3
|
|
43.0
|
|
4/19-9/19
|
November 26, 2019
|
Approved
March 31, 2020
|
April 2020
|
|
NIPSCO - Gas
|
FMCA 4(3)
|
1.6
|
|
43.2
|
|
10/19-3/20
|
May 26, 2020
|
Order Expected
September 2020
|
October 2020
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Columbia of Massachusetts
|
GSEP - 2020(3)(4)
|
0.9
|
|
37.5
|
|
1/20-12/20
|
October 31, 2019
|
Approved
April 30, 2020
|
May 2020
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Columbia of Virginia
|
SAVE - 2020
|
3.8
|
|
50.0
|
|
1/20-12/20
|
August 15, 2019
|
Approved December 6, 2019
|
January 2020
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Columbia of Virginia
|
SAVE - 2021
|
5.2
|
|
46.4
|
|
1/21-12/21
|
July 24, 2020
|
Order Expected
November 2020
|
January 2021
|
|
Columbia of Kentucky
|
SMRP - 2020
|
4.2
|
|
40.4
|
|
1/20-12/20
|
October 15, 2019
|
Approved December 20, 2019
|
January 2020
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Columbia of Maryland
|
STRIDE - 2020
|
1.3
|
|
15.0
|
|
1/20-12/20
|
January 29, 2020
|
Approved
February 19, 2020
|
February 2020
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
NIPSCO - Electric
|
TDSIC - 6
|
28.1
|
|
131.1
|
|
12/18-6/19
|
August 21, 2019
|
Approved December 18, 2019
|
January 2020
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
NIPSCO - Electric
|
FMCA - 12(3)
|
1.6
|
|
4.7
|
|
3/19-8/19
|
October 18, 2019
|
Approved
January 29, 2020
|
February 2020
|
|
NIPSCO - Electric
|
FMCA - 13(3)(5)
|
(1.2)
|
|
—
|
|
9/19-2/20
|
April 15, 2020
|
Approved
July 29, 2020
|
August 2020
|
|
Columbia of Pennsylvania
|
DSIC - Q1 2020
|
0.9
|
|
28.2
|
|
12/19-2/20
|
April 27, 2020
|
Approved
May 4, 2020
|
May 2020
|
|
Columbia of Pennsylvania
|
DSIC - Q2 2020
|
0.8
|
|
28.6
|
|
3/20-5/20
|
June 19, 2020
|
Approved
June 29, 2020
|
July 2020
|
(1)Incremental capital and revenue are net of amounts included in the step 2 rates.
(2)Incremental revenue is net of amounts included in the step 2 rates and reflects a more typical 6-month filing period.
(3)Incremental revenue is inclusive of tracker eligible operations and maintenance expense.
Table of Contents
ITEM 1. FINANCIAL STATEMENTS (continued)
NiSource Inc.
Notes to Condensed Consolidated Financial Statements (unaudited) (continued)
(4)Incremental revenue reflects a 50% decrease in projected 2020 capital investments due to the October 3, 2019 order from the Massachusetts DPU that imposed work restrictions on Columbia of Massachusetts and the Massachusetts DPU's ongoing investigations.
(5)No eligible capital investments were made during the investment period.
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
|
Requested Incremental Revenue
|
Approved or Settled Incremental Revenue
|
Filed
|
Status
|
Rates
Effective
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
NIPSCO - Electric(1)
|
$
|
21.4
|
|
$
|
(53.5)
|
|
October 31, 2018
|
Approved
December 4, 2019
|
January 2020
|
|
|
|
|
|
|
|
|
Columbia of Pennsylvania(2)
|
$
|
100.4
|
|
in process
|
April 24, 2020
|
Order Expected
Q1 2021
|
February 2021
|
|
Columbia of Maryland
|
$
|
5.0
|
|
in process
|
May 15, 2020
|
Order Expected
Q4 2020
|
December 2020
|
(1)Rates were implemented in two steps, with implementation of step 1 rates effective on January 2, 2020 and step 2 rates effective on March 2, 2020.
(2)On June 3, the Pennsylvania Commission's Chief Administrative Law Judge issued an order that postpones the suspension period for Columbia of Pennsylvania's general rate increase from the statutorily established suspension date of January 23, 2021 to February 4, 2021 for reasons related to COVID-19. Columbia of Pennsylvania is seeking the Commission's reconsideration and reversal of that order.
COVID-19 Regulatory Filings
Beginning in March 2020, moratoriums on disconnections of residential and commercial customers for non-payment of utility service and late payment fees were issued in each of the states we operate. In general, these moratoriums will continue into the third or fourth quarter of 2020, depending on the jurisdiction.
In response to COVID-19, we have engaged the regulatory commissions in the states in which we operate, as described below.
Columbia of Ohio filed a Deferral Application and a Transition Plan with the PUCO on May 29, 2020. The Deferral Application requested approval to record a regulatory asset for COVID-19 incremental costs, foregone revenue from late payment fees, and bad debt expense from certain classes of customers. An order approving the Deferral Application was received on July 15, 2020. No regulatory asset was recorded as of June 30, 2020. Recovery of any regulatory asset, when recorded, will be addressed in future proceedings. The Transition Plan requested the resumption of activities that were suspended in March 2020, including resumption of disconnects due to non-payment and billing of late payment fees beginning with the August 2020 billing cycle. The PUCO approved the Transition Plan on June 17, 2020.
NIPSCO received a COVID-19 order from the IURC on June 29, 2020. This order extended the disconnection moratorium and the suspension of collection of late payment fees, convenience fees, deposits and reconnection fees through August 14, 2020. The order requires utilities to offer payment arrangements of at least six months and requires NIPSCO to provide the IURC with information about NIPSCO’s communications with delinquent customers. The order authorized NIPSCO to create a regulatory asset for COVID-19 related incremental bad debt expense, as well as the costs to implement the requirements of the order. As of June 30, 2020, $0.7 million of incremental bad debt expense was deferred to a regulatory asset. Recovery of the regulatory asset will be addressed in future base rate proceedings.
Columbia of Pennsylvania received a secretarial letter from the Pennsylvania PUC on May 13, 2020 authorizing Columbia of Pennsylvania to create a regulatory asset for incremental bad debt expense above levels currently in rates incurred since March 13, 2020. While Columbia of Pennsylvania is not authorized to defer any other incremental costs, it is required to track costs incurred and any benefits received in connection with COVID-19. As of June 30, 2020, $0.1 million of incremental bad debt expense was deferred to a regulatory asset. Recovery of any regulatory asset will be addressed in future base rate proceedings.
Columbia of Virginia received an order from the VSCC on April 29, 2020 authorizing Columbia of Virginia to create a regulatory asset for incremental bad debt expense, suspended late payment fees, reconnection costs, carrying costs and other incremental prudently incurred costs related to COVID-19. We are evaluating the impact of the order. Recovery of any regulatory asset, when recorded, will be addressed in future base rate proceedings.
Table of Contents
ITEM 1. FINANCIAL STATEMENTS (continued)
NiSource Inc.
Notes to Condensed Consolidated Financial Statements (unaudited) (continued)
Columbia of Maryland received an order from the Maryland PSC on April 9, 2020 authorizing Columbia of Maryland to create a regulatory asset for incremental COVID-19 related costs 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 COVID-19. As of June 30, 2020, $0.3 million of incremental bad debt expense and COVID-19 related costs had been deferred to a regulatory asset. Recovery of the regulatory asset will be addressed in future base rate proceedings.
Columbia of Massachusetts is participating in two working groups established by the Massachusetts DPU to focus on customer assistance and financial ratemaking matters. Customer assistance recommendations, which enable utilities to provide flexible payment arrangements to customers who need financial assistance, were provided to Massachusetts DPU on May 29, 2020. The Massachusetts DPU issued an order on June 26, 2020 approving the customer assistance recommendations and established reporting requirements. A financial ratemaking proposal, which includes the establishment of a regulatory asset for COVID-19 related expenses and semi-annual adjustments to cash working capital, is being reviewed and discussed by the working group, including a counterproposal from the Massachusetts Attorney General’s Office.
Columbia of Kentucky is engaging with peer utilities and is working closely with the Kentucky PSC on COVID-19 developments that impact customers and utility operations, including exploring flexible payment plans for customers who need financial assistance in order to mitigate the amount of uncollectible customer receivables and tracking COVID-19 related costs.
Table of Contents
ITEM 1. FINANCIAL STATEMENTS (continued)
NiSource Inc.
Notes to Condensed Consolidated Financial Statements (unaudited) (continued)
11. 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, 2020
|
|
December 31, 2019
|
|
Risk Management Assets - Current(1)
|
|
|
|
|
Interest rate risk programs
|
$
|
—
|
|
|
$
|
—
|
|
|
Commodity price risk programs
|
15.5
|
|
|
0.6
|
|
|
Total
|
$
|
15.5
|
|
|
$
|
0.6
|
|
|
Risk Management Assets - Noncurrent(2)
|
|
|
|
|
Interest rate risk programs
|
$
|
—
|
|
|
$
|
—
|
|
|
Commodity price risk programs
|
8.5
|
|
|
3.8
|
|
|
Total
|
$
|
8.5
|
|
|
$
|
3.8
|
|
|
Risk Management Liabilities - Current
|
|
|
|
|
Interest rate risk programs
|
$
|
108.3
|
|
|
$
|
—
|
|
|
Commodity price risk programs
|
11.7
|
|
|
12.6
|
|
|
Total
|
$
|
120.0
|
|
|
$
|
12.6
|
|
|
Risk Management Liabilities - Noncurrent
|
|
|
|
|
Interest rate risk programs
|
$
|
141.8
|
|
|
$
|
76.2
|
|
|
Commodity price risk programs
|
58.2
|
|
|
57.8
|
|
|
Total
|
$
|
200.0
|
|
|
$
|
134.0
|
|
(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).
Commodity Price Risk Management
We, along with our utility customers, are exposed to variability in cash flows associated with natural gas purchases and volatility in natural gas prices. We purchase natural gas for sale and delivery to our retail, commercial and industrial customers, and for most customers the variability in the market price of gas is passed through in their rates. Some of our utility subsidiaries offer programs whereby variability in the market price of gas is assumed by the respective utility. The objective of our commodity price risk programs is to mitigate the gas cost variability, for us or on behalf of our customers, associated with natural gas purchases or sales by economically hedging the various gas cost components using a combination of futures, options, forwards or other derivative contracts.
NIPSCO received IURC approval to lock in a fixed price for its natural gas customers using long-term forward purchase instruments. The term of these instruments may range from five to ten years and is limited to 20 percent of NIPSCO’s average annual GCA purchase volume. Gains and losses on these derivative contracts are deferred as regulatory liabilities or assets and are remitted to or collected from customers through NIPSCO’s quarterly GCA mechanism. These instruments are not designated as accounting hedges.
Interest Rate Risk Management
As of June 30, 2020, we have forward-starting interest rate swaps with an aggregate notional value totaling $500.0 million to hedge the variability in cash flows attributable to changes in the benchmark interest rate during the periods from the effective dates of the swaps to the anticipated dates of forecasted debt issuances, which are expected to take place by 2024. These interest rate swaps are designated as cash flow hedges. The gains and losses related to these swaps are recorded to AOCI and are recognized in "Interest expense, net" concurrently with the recognition of interest expense on the associated debt, once issued. If it becomes probable that a hedged forecasted transaction will no longer occur, the accumulated gains or losses on the derivative will be recognized currently in "Other, net" in the Condensed Statements of Consolidated Income (Loss) (unaudited).
Table of Contents
ITEM 1. FINANCIAL STATEMENTS (continued)
NiSource Inc.
Notes to Condensed Consolidated Financial Statements (unaudited) (continued)
There were no amounts excluded from effectiveness testing for derivatives in cash flow hedging relationships at June 30, 2020 and December 31, 2019.
Our derivative instruments measured at fair value as of June 30, 2020 and December 31, 2019 do not contain any credit-risk-related contingent features.
12. 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, 2020 and December 31, 2019:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Recurring Fair Value Measurements
June 30, 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
June 30, 2020
|
|
Assets
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Risk management assets
|
$
|
—
|
|
|
$
|
24.0
|
|
|
$
|
—
|
|
|
$
|
24.0
|
|
|
|
|
|
|
|
|
|
|
|
Available-for-sale debt securities
|
—
|
|
|
155.2
|
|
|
—
|
|
|
155.2
|
|
|
Total
|
$
|
—
|
|
|
$
|
179.2
|
|
|
$
|
—
|
|
|
$
|
179.2
|
|
|
Liabilities
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Risk management liabilities
|
$
|
—
|
|
|
$
|
320.0
|
|
|
$
|
—
|
|
|
$
|
320.0
|
|
|
Total
|
$
|
—
|
|
|
$
|
320.0
|
|
|
$
|
—
|
|
|
$
|
320.0
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Recurring Fair Value Measurements
December 31, 2019 (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, 2019
|
|
Assets
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Risk management assets
|
$
|
—
|
|
|
$
|
4.4
|
|
|
$
|
—
|
|
|
$
|
4.4
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Available-for-sale debt securities
|
—
|
|
|
154.2
|
|
|
—
|
|
|
154.2
|
|
|
Total
|
$
|
—
|
|
|
$
|
158.6
|
|
|
$
|
—
|
|
|
$
|
158.6
|
|
|
Liabilities
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Risk management liabilities
|
$
|
—
|
|
|
$
|
146.6
|
|
|
$
|
—
|
|
|
$
|
146.6
|
|
|
Total
|
$
|
—
|
|
|
$
|
146.6
|
|
|
$
|
—
|
|
|
$
|
146.6
|
|
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. When utilized, exchange-traded derivative contracts are based on unadjusted quoted prices in active markets and are classified within Level 1. These financial assets and liabilities are secured with cash on deposit with the exchange; therefore, nonperformance risk has not been incorporated into these valuations. Certain non-exchange-traded derivatives are valued using broker or over-the-counter, on-line exchanges. In such cases, these non-exchange-traded derivatives are classified within Level 2. Non-exchange-based derivative instruments include swaps, forwards, and options. In certain instances, these instruments may utilize models to measure fair value. We use a similar model to value similar instruments. Valuation models utilize various inputs that include quoted prices for similar assets or liabilities in active markets, quoted prices for identical or similar assets or liabilities in markets that are not active, other observable inputs for the asset or liability and market-corroborated inputs, (i.e., inputs derived principally from or corroborated by observable market data by correlation or other means). Where observable inputs are available for substantially the full term of the asset or liability, the instrument is categorized within Level 2. Certain derivatives trade in less active markets with a lower availability of pricing information and models may be utilized in the valuation. When such inputs have a
Table of Contents
ITEM 1. FINANCIAL STATEMENTS (continued)
NiSource Inc.
Notes to Condensed Consolidated Financial Statements (unaudited) (continued)
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, 2020 and December 31, 2019, there were no material transfers between fair value hierarchies. Additionally, there were no changes in the method or significant assumptions used to estimate the fair value of our financial instruments.
We have entered into forward-starting interest rate swaps to hedge the interest rate risk on coupon payments of forecasted issuances of long-term debt. These derivatives are designated as cash flow hedges. Credit risk is considered in the fair value calculation of each agreement. As they are based on observable data and valuations of similar instruments, the hedges are categorized within Level 2 of the fair value hierarchy. There was no exchange of premium at the initial date of the swaps, and we can settle the contracts at any time. For additional information, see Note 11, "Risk Management Activities."
NIPSCO has entered into long-term forward natural gas purchase instruments that range from five to ten years to lock in a fixed price for its natural gas customers. We value these contracts using a pricing model that incorporates market-based information when available, as these instruments trade less frequently and are classified within Level 2 of the fair value hierarchy. For additional information, see Note 11, “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.
We adopted ASC 326 effective January 1, 2020. See "Recently Adopted Accounting Pronouncements" in Note 2, "Recent Accounting Pronouncements," for more information about ASC 326. Upon adoption of ASC 326, our available-for-sale debt securities impairments are recognized periodically using an allowance approach instead of an 'other than temporary' impairment model. At each reporting date, we utilize a quantitative and qualitative review process to assess the impairment of available-for-sale debt securities at the individual security level. For securities in a loss position, we evaluate our intent to sell or whether it is more-likely-than-not that we will be required to sell the security prior to the recovery of its amortized cost. If either criteria is met, the loss is recognized in earnings immediately, with the offsetting entry to the carrying value of the security. If both criteria are not met, 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 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 will be 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 will be recognized immediately in earnings instead of over-time as they would under historic guidance. During the six months ended June 30, 2020, we recorded $0.8 million 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.
Table of Contents
ITEM 1. FINANCIAL STATEMENTS (continued)
NiSource Inc.
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, 2020 and December 31, 2019 were:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
June 30, 2020 (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
|
$
|
25.8
|
|
|
$
|
0.5
|
|
|
$
|
—
|
|
|
$
|
—
|
|
|
$
|
26.3
|
|
|
Corporate/Other debt securities
|
125.6
|
|
|
6.6
|
|
|
(2.5)
|
|
|
(0.8)
|
|
|
128.9
|
|
|
Total
|
$
|
151.4
|
|
|
$
|
7.1
|
|
|
$
|
(2.5)
|
|
|
$
|
(0.8)
|
|
|
$
|
155.2
|
|
|
|
|
|
|
|
|
|
|
|
|
|
December 31, 2019 (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
|
$
|
31.4
|
|
|
$
|
0.1
|
|
|
$
|
(0.1)
|
|
|
$
|
—
|
|
|
$
|
31.4
|
|
|
Corporate/Other debt securities
|
118.7
|
|
|
4.2
|
|
|
(0.1)
|
|
|
—
|
|
|
122.8
|
|
|
Total
|
$
|
150.1
|
|
|
$
|
4.3
|
|
|
$
|
(0.2)
|
|
|
$
|
—
|
|
|
$
|
154.2
|
|
(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 $0 and $26.1 million, respectively, at June 30, 2020.
(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 $17.2 million and $12.2 million, respectively, at December 31, 2019.
Realized gains and losses on available-for-sale securities were immaterial for the three and six months ended June 30, 2020 and 2019.
The cost of maturities sold is based upon specific identification. At June 30, 2020, approximately $4.2 million of U.S. Treasury debt securities and approximately $5.0 million of Corporate/Other debt securities have maturities of less than a year.
There are no material items in the fair value reconciliation of Level 3 assets and liabilities measured at fair value on a recurring basis for the three and six months ended June 30, 2020 and 2019.
Non-recurring Fair Value Measurements
We measure the fair value of certain assets on a non-recurring basis, typically annually or when events or changes in circumstances indicate that the carrying amount of the assets may not be recoverable. These assets include goodwill.
As of June 30, 2020, the Massachusetts Business met the requirements under GAAP to be classified as held for sale, and the assets and liabilities of the Massachusetts Business are measured at fair value, less costs to sell. Our estimated total pre-tax loss for the three and six months ended June 30, 2020 is $84.4 million and $364.6 million, respectively. For additional information, see Note 7, "Assets and Liabilities Held for Sale."
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. Our long-term borrowings are recorded at historical amounts.
The following method and assumptions were used to estimate the fair value of each class of financial instruments.
Long-term Debt. The fair value of outstanding long-term debt is estimated based on the quoted market prices for the same or similar securities. Certain premium costs associated with the early settlement of long-term debt are not taken into consideration in determining fair value. These fair value measurements are classified within Level 2 of the fair value hierarchy. For the three and six months ended June 30, 2020, there was no change in the method or significant assumptions used to estimate the fair value of long-term debt.
Table of Contents
ITEM 1. FINANCIAL STATEMENTS (continued)
NiSource Inc.
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, 2020
|
|
Estimated Fair
Value as of
June 30, 2020
|
|
Carrying
Amount as of
Dec. 31, 2019
|
|
Estimated Fair
Value as of
Dec. 31, 2019
|
|
Long-term debt (including current portion)
|
$
|
8,825.8
|
|
|
$
|
10,493.6
|
|
|
$
|
7,869.6
|
|
|
$
|
8,764.4
|
|
13. Transfers of Financial Assets
Columbia of Ohio, NIPSCO and Columbia of Pennsylvania each maintain a receivables agreement whereby they transfer their customer accounts receivables to third-party financial institutions through wholly-owned and consolidated special purpose entities. The three agreements expire between August 2020 and May 2021 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, 2020, the maximum amount of debt that could be recognized related to our accounts receivable programs is $350.0 million.
The following table reflects the gross receivables balance and net receivables transferred, as well as short-term borrowings related to the securitization transactions as of June 30, 2020 and December 31, 2019:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(in millions)
|
June 30, 2020
|
|
December 31, 2019
|
|
Gross Receivables
|
$
|
467.3
|
|
|
$
|
569.1
|
|
|
Less: Receivables not transferred
|
153.8
|
|
|
215.9
|
|
|
Net receivables transferred
|
$
|
313.5
|
|
|
$
|
353.2
|
|
|
Short-term debt due to asset securitization
|
$
|
313.5
|
|
|
$
|
353.2
|
|
For the six months ended June 30, 2020 and 2019, $39.7 million and $79.2 million, respectively, was recorded as cash flows used for financing activities related to the change in short-term borrowings due to securitization transactions. Fees associated with the securitization transactions were $0.8 million and $0.6 million for the three months ended June 30, 2020 and 2019, respectively and $1.5 million and $1.4 million for the six months ended June 30, 2020 and 2019, 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.
14. Goodwill
The following presents our goodwill balance allocated by segment as of June 30, 2020:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(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, 2020, we completed a quantitative "step 1" fair value measurement of our reporting units with a goodwill balance. This analysis incorporated the latest available income statement and cash flow projections, including significant, identifiable impacts of COVID-19 on the operations of each of our goodwill reporting units. We also incorporated other significant inputs to our fair value calculations, including discount rate and market multiples, to reflect current market conditions. The step 1 analysis performed indicated that the fair value of each reporting unit that is allocated goodwill significantly exceeded its carrying value. As a result, no impairment charge was recorded as of the May 1, 2020 test date.
While our annual goodwill impairment test was performed with a valuation date of May 1, 2020, we continue to monitor events and circumstances that may indicate that it is more likely than not that the fair value of our reporting units is less than the
Table of Contents
ITEM 1. FINANCIAL STATEMENTS (continued)
NiSource Inc.
Notes to Condensed Consolidated Financial Statements (unaudited) (continued)
reporting unit carrying value, including the on-going evaluation of the impact of COVID-19. At June 30, 2020, we assessed events and circumstances related to COVID-19, including, but not limited to, general economic conditions, access to capital, developments in the equity and credit markets, the impact on NiSource's share price, the availability and cost of materials and labor, the impact on revenue and cash flow, and regulatory and political activity. The results of this assessment indicated that it was not more likely than not that the fair values of our reporting units were less than their respective carrying values at June 30, 2020.
During the fourth quarter of 2019, in connection with the preparation of the year-end financial statements, we assessed the matters related to Columbia of Massachusetts (see Note 19-B, "Legal Proceedings") and determined a quantitative "step 1" impairment analysis was required for our Columbia of Massachusetts reporting unit. The December 31, 2019 impairment analysis indicated that the fair value of the Columbia of Massachusetts reporting unit was below its carrying value. As a result, we reduced the Columbia of Massachusetts reporting unit goodwill balance to zero and recognized a goodwill impairment charge totaling $204.8 million in 2019.
15. Income Taxes
Our interim effective tax rates reflect the estimated annual effective tax rates for 2020 and 2019, adjusted for tax expense associated with certain discrete items. The effective tax rates for the three months ended June 30, 2020 and 2019 were 491.7% and 19.6%, respectively. The effective tax rates for the six months ended June 30, 2020 and 2019 were (14.5)% and 20.3%, 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.
The increase in the three month effective tax rates of 472.1% in 2020 compared to 2019 is primarily attributable to the non-deductible payment in lieu of penalties, offset by increased amortization of excess deferred federal income tax liabilities and state income taxes.
The decrease in the six month effective tax rates of 34.8% in 2020 compared to 2019 is primarily attributed to the increased amortization of excess deferred federal income tax liabilities and lower state income taxes, offset by the non-deductible payment in lieu of penalties. See Note 7, "Assets and Liabilities Held for Sale," for additional information on the payment in lieu of penalties.
There were no material changes recorded in 2020 to our uncertain tax positions recorded as of December 31, 2019.
Other CARES Act Tax Matters. The CARES Act was enacted on March 27, 2020 in response to the COVID-19 pandemic. The CARES Act contains numerous income tax provisions, such as relaxing limitations on the deductibility of interest and the use of net operating losses arising in taxable years beginning after December 31, 2017. Under the provisions of the CARES Act, we have deferred payroll tax payments of approximately $9.9 million through June 30, 2020. We continue to monitor additional guidance to clarify provisions in the CARES Act (as well as under the TCJA) to determine if such guidance could ultimately increase or lessen their impact on our business and financial condition. It is also possible that Congress and other agencies will enact additional legislation or policies in connection with COVID-19, and we will continue to assess the potential impacts of these developments on our financial position and results of operations. There are no material income tax impacts on our consolidated financial position, results of operations, and cash flows during the six months ended June 30, 2020.
16. 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. For most plans, cash contributions are remitted to grantor trusts.
For the six months ended June 30, 2020, we contributed $1.5 million to our pension plans and $11.5 million to our other postretirement benefit plans.
Table of Contents
ITEM 1. FINANCIAL STATEMENTS (continued)
NiSource Inc.
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, 2020 and 2019:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Pension Benefits
|
|
|
|
Other Postretirement
Benefits
|
|
|
|
Three Months Ended June 30, (in millions)
|
2020
|
|
2019
|
|
2020
|
|
2019
|
|
Components of Net Periodic Benefit Cost(1)
|
|
|
|
|
|
|
|
|
Service cost
|
$
|
8.0
|
|
|
$
|
7.3
|
|
|
$
|
1.6
|
|
|
$
|
1.3
|
|
|
Interest cost
|
13.5
|
|
|
18.2
|
|
|
3.9
|
|
|
4.8
|
|
|
Expected return on assets
|
(28.4)
|
|
|
(27.2)
|
|
|
(3.6)
|
|
|
(3.3)
|
|
|
Amortization of prior service credit
|
0.2
|
|
|
—
|
|
|
(0.5)
|
|
|
(0.8)
|
|
|
Recognized actuarial loss
|
8.7
|
|
|
11.4
|
|
|
1.3
|
|
|
0.5
|
|
|
|
|
|
|
|
|
|
|
|
Total Net Periodic Benefit Cost
|
$
|
2.0
|
|
|
$
|
9.7
|
|
|
$
|
2.7
|
|
|
$
|
2.5
|
|
(1)The service cost component and all non-service cost components of net periodic benefit 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)
|
2020
|
|
2019
|
|
2020
|
|
2019
|
|
Components of Net Periodic Benefit Cost(1)
|
|
|
|
|
|
|
|
|
Service cost
|
$
|
16.0
|
|
|
$
|
14.6
|
|
|
$
|
3.2
|
|
|
$
|
2.6
|
|
|
Interest cost
|
27.0
|
|
|
36.4
|
|
|
7.8
|
|
|
9.6
|
|
|
Expected return on assets
|
(56.8)
|
|
|
(54.4)
|
|
|
(7.2)
|
|
|
(6.6)
|
|
|
Amortization of prior service credit
|
0.4
|
|
|
—
|
|
|
(1.0)
|
|
|
(1.6)
|
|
|
Recognized actuarial loss
|
17.4
|
|
|
22.8
|
|
|
2.6
|
|
|
1.0
|
|
|
|
|
|
|
|
|
|
|
|
Total Net Periodic Benefit Cost
|
$
|
4.0
|
|
|
$
|
19.4
|
|
|
$
|
5.4
|
|
|
$
|
5.0
|
|
(1)The service cost component and all non-service cost components of net periodic benefit cost are presented in "Operation and maintenance" and "Other, net", respectively, on the Condensed Statements of Consolidated Income (Loss) (unaudited).
17. Long-Term Debt
On April 13, 2020, we completed our issuance and sale of $1.0 billion of 3.60% senior unsecured notes maturing in 2030, which resulted in approximately $987.8 million of net proceeds after deducting commissions and expenses.
18. Short-Term Borrowings
We generate short-term borrowings from our revolving credit facility, commercial paper program, accounts receivable transfer programs and term loan agreement. Each of these borrowing sources is described further below.
We maintain a revolving credit facility to fund ongoing working capital requirements, including the provision of liquidity support for our commercial paper program, provide for issuance of letters of credit and also for general corporate purposes. Our revolving credit facility has a program limit of $1.85 billion and is comprised of a syndicate of banks led by Barclays. We had no outstanding borrowings under this facility as of June 30, 2020 and December 31, 2019.
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, 2020 and $570.0 million of commercial paper outstanding as of December 31, 2019.
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). We had $313.5 million in transfers as of June 30, 2020 and $353.2 million in transfers as of December 31, 2019. Refer to Note 13, "Transfers of Financial Assets," for additional information.
On April 1, 2020, we terminated and repaid in full our existing $850.0 million term loan agreement with a syndicate of banks led by MUFG Bank, Ltd. and entered into a new $850.0 million term loan agreement with a syndicate of banks led by KeyBank
Table of Contents
ITEM 1. FINANCIAL STATEMENTS (continued)
NiSource Inc.
Notes to Condensed Consolidated Financial Statements (unaudited) (continued)
National Association. The term loan matures March 31, 2021, at which point any and all outstanding borrowings under the agreement are due. Interest charged on borrowings depends on the variable rate structure we elect at the time of each borrowing. The available variable rate structures from which we may choose are defined in the term loan agreement. Under the agreement, we borrowed $850.0 million on April 1, 2020 with an interest rate of LIBOR plus 75 basis points.
Short-term borrowings were as follows:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(in millions)
|
June 30,
2020
|
|
December 31,
2019
|
|
|
|
|
|
|
Commercial paper weighted-average interest rate of 2.03% at December 31, 2019
|
—
|
|
|
570.0
|
|
|
|
|
|
|
|
Accounts receivable securitization facility
|
313.5
|
|
|
353.2
|
|
|
Term loan interest rate of 0.93% and 2.40% at June 30, 2020 and December 31, 2019, respectively
|
850.0
|
|
|
850.0
|
|
|
Total Short-Term Borrowings
|
$
|
1,163.5
|
|
|
$
|
1,773.2
|
|
Other than for the term loan, revolving credit facility and certain commercial paper borrowings, cash flows related to the borrowings and repayments of the items listed above are presented net in the Condensed Statements of Consolidated Cash Flows (unaudited) as their maturities are less than 90 days.
19. 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, 2020 and December 31, 2019, we had issued stand-by letters of credit of $10.2 million.
We have provided guarantees related to our future performance under BTAs for our renewable generation projects. At June 30, 2020, our guarantees for the Rosewater and Indiana Crossroads BTAs totaled $34.0 million. In July 2020, the amount of the guarantees increased to $195.6 million with the signing of the Rosewater equity capital contribution agreement. The amount of each guaranty will decrease upon the substantial completion of the construction of the facilities. See “- D. Other Matters - NIPSCO 2018 Integrated Resource Plan,” 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 has replaced the cast iron and bare steel gas pipeline system in the affected area and restored service to nearly all of the gas meters. See “- D. Other Matters - Greater Lawrence Pipeline Replacement” below for more information.
We are subject to inquiries and investigations by government authorities and regulatory agencies regarding the Greater Lawrence Incident, including the Massachusetts DPU and the Massachusetts Attorney General's Office, as described below. We are cooperating with all inquiries and investigations. In addition, on February 26, 2020, the Company and Columbia of Massachusetts entered into agreements with the U.S. Attorney’s Office for the District of Massachusetts to resolve the U.S. Attorney’s Office’s investigation relating to the Greater Lawrence Incident, and on July 2, 2020, the Company and Columbia of Massachusetts entered into an agreement with the Massachusetts Attorney General’s Office (among other parties) to resolve the Massachusetts investigations, as described below.
NTSB Investigation. As previously disclosed, the NTSB concluded its investigation into the Greater Lawrence Incident, and we are implementing the one remaining safety recommendation resulting from the investigation.
Table of Contents
ITEM 1. FINANCIAL STATEMENTS (continued)
NiSource Inc.
Notes to Condensed Consolidated Financial Statements (unaudited) (continued)
Massachusetts Investigations. Under Massachusetts law, the Massachusetts DPU is authorized to investigate potential violations of pipeline safety regulations and to assess a civil penalty of up to $218,647 for a violation of federal pipeline safety regulations. A separate violation occurs for each day of violation up to $2.2 million for a related series of violations. The Massachusetts DPU also is authorized to investigate potential violations of the Columbia of Massachusetts emergency response plan and to assess penalties of up to $250,000 per violation per day, or up to $20.0 million per related series of violations. Further, as a result of the declaration of emergency by the Governor, the Massachusetts DPU is authorized to investigate potential violations of the Massachusetts DPU's operational directives during the restoration efforts and assess penalties of up to $1.0 million per violation. Pursuant to these authorities, the Massachusetts DPU is investigating Columbia of Massachusetts as described below, although a Settlement Agreement resolving the investigations is currently pending approval (as defined and further described below).
After the Greater Lawrence Incident, the Massachusetts DPU retained an independent evaluator to conduct a statewide examination of the safety of the natural gas distribution system and the operational and maintenance functions of natural gas companies in the Commonwealth of Massachusetts. Through authority granted by the Massachusetts Governor under the state of emergency, the Chair of the Massachusetts DPU has directed all natural gas distribution companies operating in the Commonwealth to fund the statewide examination. The statewide examination is complete. The Phase I report, which was issued in May 2019, included a program level assessment and evaluation of natural gas distribution companies. The Phase I report's conclusions were statewide and contained no specific conclusions about Columbia of Massachusetts. Phase II, which was focused on field assessments of each Massachusetts gas company, concluded in December 2019. The Phase II report made several observations about and recommendations to Massachusetts gas companies, including Columbia of Massachusetts, with regard to safety culture and assets. The final report was issued in late January 2020, and the Massachusetts DPU directed each natural gas distribution company operating in Massachusetts to submit a plan in response to the report no later than February 28, 2020. Columbia of Massachusetts submitted its plan on February 28, 2020.
On September 11, 2019, the Massachusetts DPU issued an order directing Columbia of Massachusetts to take several specific actions to address concerns related to service lines abandoned during the restoration work following the Greater Lawrence Incident and to furnish certain information and periodic reports to the Massachusetts DPU.
On October 1, 2019, the Massachusetts DPU issued four orders to Columbia of Massachusetts in connection with the service lines abandoned during the Greater Lawrence Incident restoration, which require: (1) the submission of a detailed work plan to the Massachusetts DPU, (2) the completion of quality control work on certain abandoned services, (3) the payment for a third-party independent audit, to be contracted through the Massachusetts DPU, of all gas pipeline work completed as part of the incident restoration effort, and (4) prompt and full response to any requests for information by the third-party auditor. The Massachusetts DPU retained an independent evaluator to conduct this audit, and that third party evaluated compliance with Massachusetts and federal law, as well as any other operational or safety risks that may be posed by the pipeline work. The audit scope also included Columbia of Massachusetts' operations in the Lawrence Division and other service territories as appropriate.
Also in October 2019, the Massachusetts DPU issued three additional orders requiring: (1) daily leak surveillance and reporting in areas where abandoned services are located, (2) completion by November 15, 2019 of the work plan previously submitted describing how Columbia of Massachusetts would address the estimated 2,200 locations at which an inside meter set was moved outside the property as part of the abandoned service work completed during the Greater Lawrence Incident restoration, and (3) submission of a report by December 2, 2019 showing any patterns, trends or correlations among the non-compliant work related to the abandonment of service lines, gate boxes and curb boxes during the incident restoration.
On October 3, 2019, the Massachusetts DPU notified Columbia of Massachusetts that, absent Massachusetts DPU approval, it is currently allowed to perform only emergency work on its gas distribution system throughout its service territories in Massachusetts. The restrictions do not apply to Columbia of Massachusetts’ work to address the previously identified issues with abandoned service lines and valve boxes in the Greater Lawrence, Massachusetts area. Columbia of Massachusetts is subject to daily monitoring by the Massachusetts DPU on any work that Columbia of Massachusetts conducts in Massachusetts. Such restrictions on work remain in place until modified by the Massachusetts DPU.
On October 25, 2019, the Massachusetts DPU issued two orders opening public investigations into Columbia of Massachusetts with respect to the Greater Lawrence Incident. The Massachusetts DPU opened the first investigation under its authority to determine compliance with federal and state pipeline safety laws and regulations, and to investigate Columbia of Massachusetts’ responsibility for and response to the Greater Lawrence Incident and its restoration efforts following the
Table of Contents
ITEM 1. FINANCIAL STATEMENTS (continued)
NiSource Inc.
Notes to Condensed Consolidated Financial Statements (unaudited) (continued)
incident. The Massachusetts DPU opened the second investigation under its authority to determine whether a gas distribution company has violated established standards regarding acceptable performance for emergency preparedness and restoration of service to investigate efforts by Columbia of Massachusetts to prepare for and restore service following the Greater Lawrence Incident. Separate penalties are applicable under each exercise of authority.
On December 23, 2019, the Massachusetts DPU issued an order defining the scope of its investigation into the response of Columbia of Massachusetts related to the Greater Lawrence Incident. The Massachusetts DPU identified three distinct time frames in which Columbia of Massachusetts handled emergency response and restoration directly: (1) September 13-14, 2018, (2) September 21 through December 16, 2018 (the Phase I restoration), and (3) September 27, 2019 through completion of restoration of outages resulting from the gas release event in Lawrence, Massachusetts that occurred on September 27, 2019. The Massachusetts DPU determined that it is appropriate to investigate separately, for each time period described above, the areas of response, recovery and restoration for which Columbia of Massachusetts was responsible. The Massachusetts DPU noted that it also may investigate the continued restoration and related repair work that took place after December 16, 2018 and, depending on the outcome of that investigation, may deem it appropriate to consider that period of restoration as an additional separate time period.
The Massachusetts DPU also noted that its investigation into all of the above described time periods is ongoing and that if the Massachusetts DPU determines, based on its investigation, that it is appropriate to treat the separate time frames as separate emergency events, it may impose up to the maximum statutory penalty for each event, pursuant to Mass. G.L. c. 164 Section 1J. This provision authorizes the Massachusetts DPU to investigate potential violations of the Columbia of Massachusetts emergency response plan and to assess penalties of up to $250,000 per violation per day, or up to $20 million per related series of violations.
In connection with its investigation related to the Greater Lawrence Incident, on February 4, 2020, the Massachusetts Attorney General's Office issued a request for documents primarily focused on the restoration work following the incident.
On June 22, 2020, the independent evaluator engaged by the Massachusetts DPU pursuant to the October 1, 2019 orders referenced above issued its assessment of the gas pipeline work completed as part of the incident restoration effort. The assessment included recommendations for Columbia of Massachusetts.
On July 2, 2020, the Massachusetts DPU notified Columbia of Massachusetts that all non-emergency related work to be conducted at regulator stations is suspended and directed the company to perform a review of all of its records related to regulator station facilities within the distribution system, upon completion of which Columbia of Massachusetts shall provide its findings and action plan to the Massachusetts DPU.
On July 2, 2020, NiSource, Columbia of Massachusetts, Eversource and Eversource Gas Company of Massachusetts, a wholly-owned subsidiary of Eversource (“EGMA”), filed with the Massachusetts DPU a joint petition for the approval of the purchase and sale of the Massachusetts Business (the "Transaction") as contemplated by the Asset Purchase Agreement and a proposed multi-year rate plan. The Asset Purchase Agreement provides for various closing conditions, including the receipt of the approval of the Massachusetts DPU and the final resolution or termination of all pending actions, claims and investigations, lawsuits or other legal or administrative proceedings against Columbia of Massachusetts and its affiliates under the jurisdiction of the Massachusetts DPU and all future actions, claims and investigations, lawsuits or other legal or administrative proceedings against NiSource, Columbia of Massachusetts and their affiliates relating to the Greater Lawrence Incident under the jurisdiction of the Massachusetts DPU, each as determined by NiSource in its reasonable discretion (the “DPU Required Resolution”).
The petition includes and seeks approval of a settlement agreement executed on July 2, 2020 (the “Settlement Agreement”) among, NiSource, Columbia of Massachusetts, Eversource, EGMA, the Massachusetts Attorney General’s Office ("Massachusetts AGO"), the Massachusetts Department of Energy Resources ("DOER"), and the Low-Income Weatherization and Fuel Assistance Program Network (together with NiSource, Columbia of Massachusetts, Eversource, EGMA, the Massachusetts AGO and the DOER, the “Settling Parties”). The Settlement Agreement is conditioned on its approval in full by the Massachusetts DPU no later than September 30, 2020.
If the Massachusetts DPU does not approve the Settlement Agreement in its entirety by September 30, 2020, or if, for any reason, the closing of the Transaction does not take place, the Settlement Agreement will be null and void, even if already approved by the Massachusetts DPU. Notwithstanding the foregoing, the Massachusetts Attorney General may, in her sole discretion, or DOER may, in its sole discretion, rescind the Settlement Agreement in its entirety prior to the Massachusetts
Table of Contents
ITEM 1. FINANCIAL STATEMENTS (continued)
NiSource Inc.
Notes to Condensed Consolidated Financial Statements (unaudited) (continued)
DPU’s issuance of an order approving the Settlement Agreement; provided that notice of such rescission must be filed, or submitted electronically, in writing with the Massachusetts DPU. The Settling Parties agree that the requested date of September 30, 2020 for the approval of the Settlement Agreement may be extended upon the mutual consent of the Settling Parties and notification of such extension to the Massachusetts DPU.
Set forth below are descriptions of the provisions of the Settlement Agreement related to the DPU Required Resolution. The Settlement Agreement includes other provisions, including generally provisions related to ratemaking and activities of Eversource and EGMA to occur after the closing of the Transaction and other conditions, as further described in the Settlement Agreement.
Termination of Massachusetts DPU Regulatory Matters. Under the Settlement Agreement, the Settling Parties agree that the terms of the Settlement Agreement achieve the DPU Required Resolution under the Asset Purchase Agreement. Further, under the Settlement Agreement, Columbia of Massachusetts takes responsibility for the Greater Lawrence Incident and does not contest facts in the record sufficient to support the Massachusetts DPU’s investigations into pipeline safety and emergency response in the two public investigations that the Massachusetts DPU opened pursuant to the October 25, 2019 orders referenced above (DPU 19-140 and 19-141, respectively). If adjudicated, Columbia of Massachusetts could be subject to the payment of penalties potentially up to the maximum allowed by law.
The Settling Parties also agree that, upon the closing of the Transaction, (1) all pending actions, claims, investigations, lawsuits and proceedings against NiSource, Columbia of Massachusetts and their affiliates, and all of the respective directors, officers, employees, agents and representatives of NiSource and Columbia of Massachusetts and their affiliates (such entities and individuals, collectively referred to as the “Discharged Persons”), under the Massachusetts DPU’s jurisdiction, shall be considered settled, resolved, and terminated; and (2) all future actions, claims, investigations, lawsuits and proceedings, whether known or unknown, against the Discharged Persons, in each case, relating to, arising out of, or in connection with the Greater Lawrence Incident (as defined in the Asset Purchase Agreement), under the jurisdiction of the Massachusetts DPU shall be considered settled, resolved, and terminated. This includes the Massachusetts DPU’s investigations into pipeline safety and emergency response in DPU 19-140 and 19-141, respectively, as well as any other regulatory matters that could have been raised by the Massachusetts DPU relating to, arising out of, or in connection with the Greater Lawrence Incident.
The Settling Parties also agree that, upon the closing of the Transaction, all pending actions, claims, investigations, lawsuits, and proceedings against the Discharged Persons, which are the subject of the Consent Order, shall be settled, resolved, and terminated. The “Consent Order” is a consent order the Massachusetts DPU will be issuing in DPU 19-140, including Compliance Actions (as defined in the Consent Order) that correspond to the entirety of cases pending before the Massachusetts DPU. The Settling Parties further agreed, upon the closing of the Transaction, that the Consent Order (and the Massachusetts DPU’s associated Compliance Actions) addresses all outstanding pipeline safety compliance investigations, inquiries, or ongoing matters, regardless of whether subject to notices of probable violations (NOPVs) or related to the Greater Lawrence Incident, existing as of the execution date of the Settlement Agreement.
Termination of Massachusetts AGO Matters. Under the Settlement Agreement, the Settling Parties agree that, upon the closing of the Transaction, the Settlement Agreement shall constitute receipt from the Massachusetts AGO of an agreement, settlement, compromise, and consent: (1) to terminate with prejudice all pending actions, claims, lawsuits, investigations, or proceedings under the jurisdiction of the Massachusetts AGO against the Discharged Persons relating, arising out of, or in connection with, the Greater Lawrence Incident; and (2) not to commence on its own behalf any new action, claim, lawsuit, investigation or proceeding against any of the Discharged Persons relating, arising out of, or in connection with, the Greater Lawrence Incident.
Payment in Lieu of Penalties. Under the Settlement Agreement, the Settling Parties agree that, at the closing of the Transaction, NiSource will make a payment in lieu of penalties in full settlement of all of the pending and potential claims, lawsuits, investigations or proceedings settled by and released by the Settlement Agreement in the amount of $56.0 million. This payment will be withheld from the proceeds received from Eversource at the closing of the Transaction. See Note 7, "Assets and Liabilities Held for Sale," for additional information.
Energy Relief Fund. Under the Settlement Agreement, the Settling Parties agree that the funds derived from the NiSource payment described above will be used to create an “Energy Relief Fund,” comprised of two components, designated as the “Merrimack Valley Renewal Fund” and the “Arrearage Forgiveness Fund,” in each case as further described in the Settlement Agreement. The Merrimack Valley Renewal Fund shall be jointly administered by the Massachusetts AGO and DOER. The Arrearage Forgiveness Fund shall be jointly administered by the Massachusetts AGO and Eversource.
Table of Contents
ITEM 1. FINANCIAL STATEMENTS (continued)
NiSource Inc.
Notes to Condensed Consolidated Financial Statements (unaudited) (continued)
Massachusetts Legislative Matters. Increased scrutiny related to gas system safety and regulatory oversight in Massachusetts, including new legislative proposals, is expected to continue during the current two year legislative session that ends in December 2020. To date, the Joint Committee on Telecommunications, Utilities and Energy has advanced two separate bills related to gas system safety to the House and Senate Ways and Means Committees for consideration.
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").
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 paid within 30 days of sentencing; (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. Columbia of Massachusetts has retained the in-house monitor.
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.
U.S. Congressional Activity. On September 30, 2019, the U.S. Pipeline Safety Act expired. There is no effect on PHMSA's authority. Action on past re-authorization bills has extended past the expiration date and action on this re-authorization is expected to continue well into 2020. Pipeline safety jurisdiction resides with the U.S. Senate Commerce Committee and is divided between two committees in the U.S. House of Representatives (Energy and Commerce, and Transportation and Infrastructure). Legislative proposals are currently in various stages of committee development and the timing of further action is uncertain. Certain legislative proposals, if enacted into law, may increase costs for natural gas industry companies, including the Company and Columbia of Massachusetts.
Private Actions. Various lawsuits, including several purported class action lawsuits, have been filed by various affected residents or businesses in Massachusetts state courts against the Company and/or Columbia of Massachusetts in connection with the Greater Lawrence Incident. A special judge has been appointed to hear all pending and future cases and the class actions have been consolidated into one class action. On January 14, 2019, the special judge granted the parties’ joint motion to stay all cases until April 30, 2019 to allow mediation, and the parties subsequently agreed to extend the stay until July 25, 2019. The class action lawsuits allege varying causes of action, including those for strict liability for ultra-hazardous activity, negligence, private nuisance, public nuisance, premises liability, trespass, breach of warranty, breach of contract, failure to
Table of Contents
ITEM 1. FINANCIAL STATEMENTS (continued)
NiSource Inc.
Notes to Condensed Consolidated Financial Statements (unaudited) (continued)
warn, unjust enrichment, consumer protection act claims, negligent, reckless and intentional infliction of emotional distress and gross negligence, and seek actual compensatory damages, plus treble damages, and punitive damages.
On July 26, 2019, the Company, Columbia of Massachusetts and NiSource Corporate Services Company, a subsidiary of the Company, entered into a term sheet with the class action plaintiffs under which they agreed to settle the class action claims in connection with the Greater Lawrence Incident. Columbia of Massachusetts agreed to pay $143 million into a settlement fund to compensate the settlement class and the settlement class agreed to release Columbia of Massachusetts and affiliates from all claims arising out of or related to the Greater Lawrence Incident. The following claims are not covered under the proposed settlement because they are not part of the consolidated class action: (1) physical bodily injury and wrongful death; (2) insurance subrogation, whether equitable, contractual or otherwise; and (3) claims arising out of appliances that are subject to the Massachusetts DPU orders. Emotional distress and similar claims are covered under the proposed settlement unless they are secondary to a physical bodily injury. The settlement class is defined under the term sheet as all persons and businesses in the three municipalities of Lawrence, Andover and North Andover, Massachusetts, subject to certain limited exceptions. The motion for preliminary approval and the settlement documents were filed on September 25, 2019. The preliminary approval court hearing was held on October 7, 2019 and the court issued an order granting preliminary approval of the settlement on October 11, 2019. The 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. In addition, the Commonwealth of Massachusetts is seeking reimbursement from Columbia of Massachusetts for its expenses incurred in connection with the Greater Lawrence Incident. The outcomes and impacts of such private actions are uncertain at this time.
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 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 claims related to the Company’s proxy statement disclosures regarding its safety systems. The remedies sought include damages for the alleged breaches of fiduciary duty, corporate governance reforms, and restitution of any unjust enrichment. The defendants have filed a motion to dismiss the lawsuit. Because of the preliminary nature of this lawsuit, the Company is not able to estimate a loss or range of loss, if any, that may be incurred in connection with this matter at this time.
Financial Impact. Since the Greater Lawrence Incident, we have recorded expenses of approximately $1,039 million for third-party claims and fines, penalties and settlements associated with government investigations. We estimate that total costs related to third-party claims and fines, penalties and settlements associated with government investigations resulting from the incident will range from $1,039 million to $1,055 million, depending on the number, nature, final outcome and value of third-party claims and the final outcome of government investigations. With regard to third-party claims, these costs include, but are not limited to, personal injury and property damage claims, damage to infrastructure, business interruption claims, and mutual aid payments to other utilities assisting with the restoration effort. These costs do not include costs of certain third-party claims and fines, penalties or settlements associated with government investigations that we are not able to estimate. These costs also do not include non-claims related and government investigation-related legal expenses resulting from the incident, the capital cost of the pipeline replacement and the payment in lieu of penalties, which are set forth in " - D. Other Matters - Greater Lawrence Incident Restoration," "- Greater Lawrence Incident Pipeline Replacement," and Note 7, "Assets and Liabilities Held for Sale," respectively.
The process for estimating costs associated with third-party claims and fines, penalties, and settlements associated with government investigations relating to the Greater Lawrence Incident requires management to exercise significant judgment based on a number of assumptions and subjective factors. As more information becomes known, including additional information regarding ongoing investigations, management’s estimates and assumptions regarding the financial impact of the Greater Lawrence Incident may change.
The aggregate amount of third-party liability insurance coverage available for losses arising from the Greater Lawrence Incident is $800 million. We have collected the entire $800 million. Total expenses related to the incident have exceeded the total amount of insurance coverage available under our policies. Refer to "- D. Other Matters - Greater Lawrence Incident Restoration," below for a summary of third-party claims-related expense activity and associated insurance recoveries recorded since the Greater Lawrence Incident.
Table of Contents
ITEM 1. FINANCIAL STATEMENTS (continued)
NiSource Inc.
Notes to Condensed Consolidated Financial Statements (unaudited) (continued)
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.
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.
C. 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 significant portion of environmental assessment and remediation costs to be recoverable through rates for certain of our companies.
As of June 30, 2020 and December 31, 2019, we had recorded a liability of $97.4 million and $104.4 million, respectively, to cover environmental remediation at various sites. The current portion of this liability is included in "Legal and environmental" 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 currently enacted laws and regulations, the nature and extent of impact and the method of remediation. These expenditures are not currently estimable at some sites. We periodically adjust our liability as information is collected and estimates become more refined.
Electric Operations' compliance estimates disclosed below are reflective of NIPSCO's Integrated Resource Plan submitted to the IURC on October 31, 2018. See section D, "Other Matters NIPSCO 2018 Integrated Resource Plan," below for additional information.
Air
Future legislative and regulatory programs could significantly limit allowed GHG emissions or impose a cost or tax on GHG emissions. Additionally, rules that require further GHG reductions or impose additional requirements for natural gas facilities could impose additional costs. NiSource will carefully monitor all GHG reduction proposals and regulations.
ACE Rule. On July 8, 2019, the EPA published the final ACE rule, which establishes emission guidelines for states to use when developing plans to limit carbon dioxide at coal-fired electric generating units based on heat rate improvement measures. The coal-fired units at NIPSCO’s R.M. Schahfer Generating Station and Michigan City Generating Station are potentially affected sources, and compliance requirements for these units, which NIPSCO plans to retire by 2023 and 2028, respectively, will be determined by future Indiana rulemaking. The ACE rule notes that states have “broad flexibility in setting standards of performance for designated facilities” and that a state may set a “business as usual” standard for sources that have a remaining useful life “so short that imposing any costs on the electric generating unit is unreasonable.” State plans are due by 2022, and the EPA will have six months to determine completeness and then one additional year to determine whether to approve the submitted plan. States have the discretion to determine the compliance period for each source. As a result, NIPSCO will continue to monitor this matter and cannot estimate its impact at this time.
Table of Contents
ITEM 1. FINANCIAL STATEMENTS (continued)
NiSource Inc.
Notes to Condensed Consolidated Financial Statements (unaudited) (continued)
Waste
CERCLA. Our subsidiaries are potentially responsible parties at waste disposal sites under the CERCLA (commonly known as Superfund) and similar state laws. Under CERCLA, each potentially responsible party can be held jointly, severally and strictly liable for the remediation costs as the EPA, or state, can allow the parties to pay for remedial action or perform remedial action themselves and request reimbursement from the potentially responsible parties. Our affiliates have retained CERCLA environmental liabilities, including remediation liabilities, associated with certain current and former operations. These liabilities are not material to the Condensed Consolidated Financial Statements (unaudited).
MGP. A program has been instituted to identify and investigate former MGP sites where Gas Distribution Operations subsidiaries or predecessors may have liability. The program has identified 63 such sites where liability is probable. Remedial actions at many of these sites are being overseen by state or federal environmental agencies through consent agreements or voluntary remediation agreements.
We utilize a probabilistic model to estimate our future remediation costs related to MGP sites. The model was prepared with the assistance of a third party and incorporates our experience and general industry experience with remediating MGP sites. We complete an annual refresh of the model in the second quarter of each fiscal year. No material changes to the estimated future remediation costs were noted as a result of the refresh completed as of June 30, 2020. Our total estimated liability related to the facilities subject to remediation was $92.0 million and $102.2 million at June 30, 2020 and December 31, 2019, respectively. The liability represents our best estimate of the probable cost to remediate the facilities. We believe that it is reasonably possible that remediation costs could vary by as much as $20 million in addition to the costs noted above. Remediation costs are estimated based on the best available information, applicable remediation standards at the balance sheet date and experience with similar facilities.
CCRs. On April 17, 2015, the EPA issued a final rule for regulation of CCRs. The rule regulates CCRs under the RCRA Subtitle D, which determines them to be nonhazardous. The rule is implemented in phases and requires increased groundwater monitoring, reporting, recordkeeping and posting of related information to the Internet. The rule also establishes requirements related to CCR management and disposal. The rule allows NIPSCO to continue its byproduct beneficial use program.
To comply with the rule, NIPSCO completed capital expenditures to modify its infrastructure and manage CCRs during 2019. The CCR rule also resulted in revisions to previously recorded legal obligations associated with the retirement of certain NIPSCO facilities. The actual asset retirement costs related to the CCR rule may vary substantially from the estimates used to record the increased asset retirement obligation due to the uncertainty about the requirements that will be established by environmental authorities, compliance strategies that will be used, and the preliminary nature of available data used to estimate costs. As allowed by the rule, NIPSCO will continue to collect data over time to determine the specific compliance solutions and associated costs and, as a result, the actual costs may vary. NIPSCO has filed initial CCR closure plans for R.M. Schahfer Generating Station and Michigan City Generating Station with the Indiana Department of Environmental Management.
Water
ELG. On November 3, 2015, the EPA issued a final rule to amend the ELG and standards for the Steam Electric Power Generating category. Based upon a study performed in 2016 of the final rule, capital compliance costs were expected to be approximately $170 million. The EPA has proposed revisions to the final rule. NIPSCO does not anticipate material ELG compliance costs based on the preferred option announced as part of NIPSCO's 2018 Integrated Resource Plan (discussed below).
D. Other Matters.
NIPSCO 2018 Integrated Resource Plan. Multiple factors, but primarily economic ones, including low natural gas prices, advancing cost effective renewable technology and increasing capital and operating costs associated with existing coal plants, have led NIPSCO to conclude in its October 2018 Integrated Resource Plan submission that NIPSCO’s current fleet of coal generation facilities will be retired earlier than previous Integrated Resource Plan’s had indicated.
The Integrated Resource Plan evaluated demand-side and supply-side resource alternatives to reliably and cost effectively meet NIPSCO customers' future energy requirements over the ensuing 20 years. The preferred option within the Integrated Resource Plan retires R.M. Schahfer Generating Station (Units 14, 15, 17, and 18) by 2023 and Michigan City Generating Station (Unit 12) by 2028. These units represent 2,080 MW of generating capacity, equal to 72% of NIPSCO’s remaining generating capacity and 100% of NIPSCO's remaining coal-fired generating capacity.
Table of Contents
ITEM 1. FINANCIAL STATEMENTS (continued)
NiSource Inc.
Notes to Condensed Consolidated Financial Statements (unaudited) (continued)
In the second quarter of 2020, the MISO approved NIPSCO's plan to retire the R.M. Schahfer Generating Station units in 2023. In accordance with ASC 980-360, the net book value of certain plant and equipment for the R.M. Schahfer Generating Station units was reclassified from "Net utility plant" to "Other property, at cost, less accumulated depreciation" on the Condensed Consolidated Balance Sheets (unaudited). The December 2019 NIPSCO electric rate case order included approval to create a regulatory asset upon the retirement of R.M. Schahfer Generating Station units in 2023. The order allows for the recovery of and on the net book value of the units by the end of 2032. Refer to Note 8, "Property, Plant and Equipment" for further information.
In connection with the MISO's approval of NIPSCO's planned retirement of the R.M. Schahfer Generating Station units, we recorded $4.6 million of plant retirement-related charges in the second quarter of 2020. These charges were 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. These charges are presented within "Operation and maintenance" on the Condensed Statements of Consolidated Income (Loss). As the retirement date approaches and more information becomes available, additional plant retirement-related charges may be incurred.
In connection with the planned retirement of the Schahfer Generating Station and Michigan City Generating Station units, the current capacity replacement plan includes lower-cost, reliable, cleaner energy resources to be obtained through a combination of NIPSCO ownership and PPAs. To this effect, NIPSCO has entered into a number of agreements with counterparties, as described below.
In January 2019, NIPSCO executed a 20 year PPA, referred to as the Jordan Creek PPA, to purchase 100% of the output from renewable generation facilities at a fixed price per MWh. The facility supplying the energy will have a nameplate wind capacity of approximately 400 MW. NIPSCO submitted the Jordan Creek PPA to the IURC for approval in February 2019 and the IURC approved the Jordan Creek PPA on June 5, 2019. Payments under the Jordan Creek PPA will not begin until the associated generation facility is constructed by the owner / seller, which is currently scheduled to be complete by the end of 2020. NIPSCO is monitoring any possible impact COVID-19 may have on the expected completion date of this project.
Also in January 2019, NIPSCO executed a BTA, referred to as the Rosewater BTA, with a developer to construct a renewable generation facility with a nameplate wind capacity of approximately 100 MW. Ownership of the facility will be transferred to a joint venture whose members include NIPSCO, the developer and an unrelated tax equity partner. NIPSCO and the tax equity partner will make cash contributions to the partnership at the date construction is substantially complete. The aforementioned joint venture is expected to be fully owned by NIPSCO after the wind PTCs are monetized from the project (approximately 10 years after the facility goes into service). NIPSCO's purchase requirement under the Rosewater BTA is dependent on satisfactory approval of the Rosewater BTA by the IURC, successful execution of an agreement with a tax equity partner and timely completion of construction. NIPSCO submitted the Rosewater BTA to the IURC for approval in February 2019 and the IURC approved the Rosewater BTA on August 7, 2019. The required FERC approvals for the project were received in December 2019. NIPSCO executed an equity capital contribution agreement with a tax equity partner in July 2020. Construction of the facility is scheduled to be completed by the end of 2020; however, this project could experience a construction delay due to COVID-19. NIPSCO is continuing to monitor the impact of COVID-19.
On October 1, 2019, NIPSCO announced the opening of its next round of RFP to consider potential resources to meet the future electric needs of its customers. The RFP closed on November 20, 2019, and NIPSCO continues to evaluate the results. NIPSCO is considering all sources in the RFP process and is expecting to obtain adequate resources to facilitate the retirement of the R.M. Schahfer Generation Station in 2023. The planned replacement in 2023 of approximately 1,400 MW from this coal-fired generation station could provide incremental capital investment opportunities for 2022 and 2023. Currently, half of the capacity in the replacement plan is targeted to be owned by joint ventures that will include NIPSCO and unrelated financial investors as the members. The remaining new capacity is expected to be primarily in the form of PPAs. NIPSCO has initiated the appropriate regulatory compliance filings related to the new capacity, starting with two solar PPAs filed with the IURC in July 2020. We expect to continue finalizing agreements with counterparties and initiating regulatory compliance filings into 2021.
In October 2019, NIPSCO executed a BTA, referred to as the Indiana Crossroads BTA, with a developer to construct an additional renewable generation facility with a nameplate wind capacity of approximately 300 MW. Ownership of the facility will be transferred to a joint venture whose members include NIPSCO, the developer and an unrelated tax equity partner. NIPSCO and the tax equity partner will make cash contributions to the partnership at the date construction is substantially complete. The aforementioned joint venture is expected to be fully owned by NIPSCO after the wind PTCs are monetized from the project (approximately 10 years after the facility goes into service). NIPSCO's purchase requirement under the Indiana
Table of Contents
ITEM 1. FINANCIAL STATEMENTS (continued)
NiSource Inc.
Notes to Condensed Consolidated Financial Statements (unaudited) (continued)
Crossroads BTA is dependent on satisfactory approval of the Indiana Crossroads BTA by the IURC, successful execution of an agreement with a tax equity partner, and timely completion of construction. NIPSCO submitted the Indiana Crossroads BTA to the IURC for approval on October 22, 2019, and the IURC approved the Indiana Crossroads BTA on February 19, 2020. Required FERC filings are expected to be filed in the second half of 2020. Construction of the facility is expected to be completed by the end of 2021.
In June 2020, NIPSCO executed three additional 20 year PPAs to purchase 100% of the output from renewable generation facilities at a fixed price per MWh. The facilities supplying the energy will have a combined nameplate solar capacity of approximately 500 MW and 30 MW storage capacity. NIPSCO's purchase requirement under the PPAs is dependent on satisfactory approval of the PPAs by the IURC. NIPSCO submitted two of the PPAs to the IURC for approval in July 2020. NIPSCO plans to submit the third PPA to the IURC for approval in the second half of 2020. If approved by the IURC, payments under the PPAs will not begin until the associated generation facilities are constructed by the owner / seller, which is expected to be complete by the second quarter of 2023.
On May 1, 2020, President Donald Trump issued an executive order (the “EO”) prohibiting any transaction initiated after that day that (i) involves bulk-power system equipment designed, developed, manufactured or supplied by persons owned by, controlled by or subject to the jurisdiction or direction of a foreign adversary and (ii) poses an unacceptable risk to national security. The EO directs the U.S. Secretary of Energy to issue implementing regulations by September 28, 2020. The EO also requires the U.S. Secretary of Energy to review the risk of existing bulk-power system equipment sourced from foreign adversaries and to establish a task force to review and recommend federal procurement policies and procedures consistent with the considerations identified in the EO. In the future, certain bulk-power system equipment owned or operated by NiSource could possibly be considered to be sourced from a foreign adversary within the meaning of the EO.
Greater Lawrence Incident Restoration. In addition to the amounts estimated for third-party claims and fines, penalties and settlements associated with government investigations described above, since the Greater Lawrence Incident, we have recorded expenses of approximately $436 million for other incident-related costs. We estimate that total other incident-related costs will range from $445 million and $455 million, depending on the incurrence of costs associated with resolving outstanding inquiries and investigations discuss above in " - B. Legal Proceedings." Such costs include certain consulting costs, legal costs, vendor costs, claims center costs, labor and related expenses incurred in connection with the incident, and insurance-related loss surcharges. The amounts set forth above do not include the capital cost of the pipeline replacement, which is set forth below, or any estimates for fines and penalties, which are discussed above in " - B. Legal Proceedings."
As discussed in "- B. Legal Proceedings," the aggregate amount of third-party liability insurance coverage available for losses arising from the Greater Lawrence Incident is $800 million. We have collected the entire $800 million. Expenses related to the incident have exceeded the total amount of insurance coverage available under our policies.
The following table summarizes expenses incurred and insurance recoveries recorded since the Greater Lawrence Incident. This activity is presented within "Operation and maintenance" and "Other, net' in our Condensed Statements of Consolidated Income (Loss) (unaudited).
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Total Costs Incurred through
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Costs Incurred during the Three Months Ended
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Costs Incurred during the Six Months Ended
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(in millions)
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December 31, 2019
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June 30, 2020
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Incident to Date
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Third-party claims
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$
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1,041
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$
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(2)
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$
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(2)
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$
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1,039
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Other incident-related costs
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420
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7
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16
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436
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Total
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1,461
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5
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14
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1,475
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Insurance recoveries recorded
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(800)
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—
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—
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(800)
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Total costs incurred
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$
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661
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$
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5
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$
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14
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$
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675
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Greater Lawrence Pipeline Replacement. In connection with the Greater Lawrence Incident, Columbia of Massachusetts, in cooperation with the Massachusetts Governor’s office, replaced the entire affected 45-mile cast iron and bare steel pipeline system that delivers gas to approximately 7,500 gas meters, the majority of which serve residences and approximately 700 of which serve businesses impacted in the Greater Lawrence Incident. This system was replaced with plastic distribution mains and service lines, as well as enhanced safety features such as pressure regulation and excess flow valves at each premise.
Table of Contents
ITEM 1. FINANCIAL STATEMENTS (continued)
NiSource Inc.
Notes to Condensed Consolidated Financial Statements (unaudited) (continued)
We have invested approximately $258 million of capital spend for the pipeline replacement; this work was completed in 2019. We maintain property insurance for gas pipelines and other applicable property. Columbia of Massachusetts has filed a proof of loss with its property insurer for the full cost of the pipeline replacement. In January 2020, we filed a lawsuit against the property insurer, seeking payment of our property claim. We are currently unable to predict the timing or amount of any insurance recovery under the property policy. This pipeline replacement cost is part of the Massachusetts Business that is classified as held for sale at June 30, 2020. The assets and liabilities of the Massachusetts Business have been recorded at fair value, less costs to sell, which has resulted in a loss being recorded as of June 30, 2020. See Note 7, "Assets and Liabilities Held for Sale," for additional information.
State Income Taxes Related to Greater Lawrence Incident Expenses. As of December 31, 2018, expenses related to the Greater Lawrence Incident were $1,023 million. In the fourth quarter of 2019, we filed an application for Alternative Apportionment with the MA DOR to request an allocable approach to these expenses for purposes of Massachusetts state income taxes, which, if approved, would result in a state deferred tax asset of approximately $50 million, net. The MA DOR issued a denial during the first quarter of 2020. We filed an application for abatement in the second quarter of 2020 and believe it is reasonably possible that the application will be accepted or an alternative method will be proposed by the MA DOR within the next six to nine months.
Voluntary Separation Program. On August 5, 2020, we commenced a voluntary separation program for certain employees. Expense for the voluntary separation program will be recognized in the period when the employee accepts the offer, absent a retention period. Otherwise, expense will be recognized over the remaining service period. Employee acceptance under the voluntary separation program is determined by management based on facts and circumstances of the benefits being offered. As the voluntary separation program commenced August 5, 2020, and benefits are dependent upon the employees who elect to participate in, and ultimately qualify for, the program, we did not recognize any expense for the program for the three and six months ended June 30, 2020.
20. Accumulated Other Comprehensive Loss
The following tables display the components of Accumulated Other Comprehensive Loss:
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|
|
Three Months Ended June 30, 2020 (in millions)
|
Gains and Losses on Securities(1)
|
|
Gains and Losses on Cash Flow Hedges(1)
|
|
Pension and OPEB Items(1)
|
|
Accumulated
Other
Comprehensive
Loss(1)
|
|
Balance as of April 1, 2020
|
$
|
(2.1)
|
|
|
$
|
(210.5)
|
|
|
$
|
(18.0)
|
|
|
$
|
(230.6)
|
|
|
Other comprehensive income before reclassifications
|
6.0
|
|
|
2.7
|
|
|
—
|
|
|
8.7
|
|
|
Amounts reclassified from accumulated other comprehensive income (loss)
|
(0.3)
|
|
|
—
|
|
|
0.3
|
|
|
—
|
|
|
Net current-period other comprehensive income
|
5.7
|
|
|
2.7
|
|
|
0.3
|
|
|
8.7
|
|
|
|
|
|
|
|
|
|
|
|
Balance as of June 30, 2020
|
$
|
3.6
|
|
|
$
|
(207.8)
|
|
|
$
|
(17.7)
|
|
|
$
|
(221.9)
|
|
|
(1)All amounts are net of tax. Amounts in parentheses indicate debits.
|
|
|
|
|
|
|
|
|
Six Months Ended June 30, 2020 (in millions)
|
Gains and Losses on Securities(1)
|
|
Gains and Losses on Cash Flow Hedges(1)
|
|
Pension and OPEB Items(1)
|
|
Accumulated
Other
Comprehensive
Loss(1)
|
|
Balance as of January 1, 2020
|
$
|
3.3
|
|
|
$
|
(77.2)
|
|
|
$
|
(18.7)
|
|
|
$
|
(92.6)
|
|
|
Other comprehensive income (loss) before reclassifications
|
0.8
|
|
|
(130.6)
|
|
|
0.4
|
|
|
(129.4)
|
|
|
Amounts reclassified from accumulated other comprehensive income (loss)
|
(0.5)
|
|
|
—
|
|
|
0.6
|
|
|
0.1
|
|
|
Net current-period other comprehensive income (loss)
|
0.3
|
|
|
(130.6)
|
|
|
1.0
|
|
|
(129.3)
|
|
|
|
|
|
|
|
|
|
|
|
Balance as of June 30, 2020
|
$
|
3.6
|
|
|
$
|
(207.8)
|
|
|
$
|
(17.7)
|
|
|
$
|
(221.9)
|
|
(1)All amounts are net of tax. Amounts in parentheses indicate debits.
Table of Contents
ITEM 1. FINANCIAL STATEMENTS (continued)
NiSource Inc.
Notes to Condensed Consolidated Financial Statements (unaudited) (continued)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended June 30, 2019 (in millions)
|
Gains and Losses on Securities(1)
|
|
Gains and Losses on Cash Flow Hedges(1)
|
|
Pension and OPEB Items(1)
|
|
Accumulated
Other
Comprehensive
Loss(1)
|
|
Balance as of April 1, 2019
|
$
|
0.4
|
|
|
$
|
(32.3)
|
|
|
$
|
(20.9)
|
|
|
$
|
(52.8)
|
|
|
Other comprehensive income (loss) before reclassifications
|
2.3
|
|
|
(30.5)
|
|
|
—
|
|
|
(28.2)
|
|
|
Amounts reclassified from accumulated other comprehensive income (loss)
|
(0.2)
|
|
|
—
|
|
|
0.4
|
|
|
0.2
|
|
|
Net current-period other comprehensive income (loss)
|
2.1
|
|
|
(30.5)
|
|
|
0.4
|
|
|
(28.0)
|
|
|
|
|
|
|
|
|
|
|
|
Balance as of June 30, 2019
|
$
|
2.5
|
|
|
$
|
(62.8)
|
|
|
$
|
(20.5)
|
|
|
$
|
(80.8)
|
|
|
(1)All amounts are net of tax. Amounts in parentheses indicate debits.
|
|
|
|
|
|
|
|
|
Six Months Ended June 30, 2019 (in millions)
|
Gains and Losses on Securities(1)
|
|
Gains and Losses on Cash Flow Hedges(1)
|
|
Pension and OPEB Items(1)
|
|
Accumulated
Other
Comprehensive
Loss(1)
|
|
Balance as of January 1, 2019
|
$
|
(2.4)
|
|
|
$
|
(13.0)
|
|
|
$
|
(21.8)
|
|
|
$
|
(37.2)
|
|
|
Other comprehensive income (loss) before reclassifications
|
5.0
|
|
|
(49.8)
|
|
|
0.5
|
|
|
(44.3)
|
|
|
Amounts reclassified from accumulated other comprehensive income (loss)
|
(0.1)
|
|
|
—
|
|
|
0.8
|
|
|
0.7
|
|
|
Net current-period other comprehensive income (loss)
|
4.9
|
|
|
(49.8)
|
|
|
1.3
|
|
|
(43.6)
|
|
|
|
|
|
|
|
|
|
|
|
Balance as of June 30, 2019
|
$
|
2.5
|
|
|
$
|
(62.8)
|
|
|
$
|
(20.5)
|
|
|
$
|
(80.8)
|
|
(1)All amounts are net of tax. Amounts in parentheses indicate debits.
21. Other, Net
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended
June 30,
|
|
|
|
Six Months Ended
June 30,
|
|
|
|
(in millions)
|
2020
|
|
2019
|
|
2020
|
|
2019
|
|
Interest income
|
$
|
1.4
|
|
|
$
|
1.2
|
|
|
$
|
3.1
|
|
|
$
|
3.3
|
|
|
AFUDC equity
|
1.4
|
|
|
2.5
|
|
|
3.1
|
|
|
4.2
|
|
|
|
|
|
|
|
|
|
|
|
Pension and other postretirement non-service cost
|
3.1
|
|
|
(3.1)
|
|
|
5.8
|
|
|
(5.9)
|
|
|
|
|
|
|
|
|
|
|
|
Miscellaneous
|
0.6
|
|
|
(0.9)
|
|
|
(0.1)
|
|
|
(2.6)
|
|
|
Total Other, net
|
$
|
6.5
|
|
|
$
|
(0.3)
|
|
|
$
|
11.9
|
|
|
$
|
(1.0)
|
|
22. Business Segment Information
At June 30, 2020, our operations are divided into two primary reportable segments. The Gas Distribution Operations segment provides natural gas service and transportation for residential, commercial and industrial customers in Ohio, Pennsylvania, Virginia, Kentucky, Maryland, Indiana and Massachusetts. The Electric Operations segment provides electric service in 20 counties in the northern part of Indiana.
Table of Contents
ITEM 1. FINANCIAL STATEMENTS (continued)
NiSource Inc.
Notes to Condensed Consolidated Financial Statements (unaudited) (continued)
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.
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended
June 30,
|
|
|
|
Six Months Ended
June 30,
|
|
|
|
(in millions)
|
2020
|
|
2019
|
|
2020
|
|
2019
|
|
Operating Revenues
|
|
|
|
|
|
|
|
|
Gas Distribution Operations
|
|
|
|
|
|
|
|
|
Unaffiliated
|
$
|
606.3
|
|
|
$
|
603.8
|
|
|
$
|
1,834.3
|
|
|
$
|
2,042.6
|
|
|
Intersegment
|
3.0
|
|
|
3.3
|
|
|
6.0
|
|
|
6.6
|
|
|
Total
|
609.3
|
|
|
607.1
|
|
|
1,840.3
|
|
|
2,049.2
|
|
|
Electric Operations
|
|
|
|
|
|
|
|
|
Unaffiliated
|
356.2
|
|
|
406.4
|
|
|
733.5
|
|
|
837.2
|
|
|
Intersegment
|
0.2
|
|
|
0.2
|
|
|
0.4
|
|
|
0.4
|
|
|
Total
|
356.4
|
|
|
406.6
|
|
|
733.9
|
|
|
837.6
|
|
|
Corporate and Other
|
|
|
|
|
|
|
|
|
Unaffiliated
|
0.2
|
|
|
0.2
|
|
|
0.4
|
|
|
0.4
|
|
|
Intersegment
|
100.7
|
|
|
114.2
|
|
|
207.4
|
|
|
225.3
|
|
|
Total
|
100.9
|
|
|
114.4
|
|
|
207.8
|
|
|
225.7
|
|
|
Eliminations
|
(103.9)
|
|
|
(117.7)
|
|
|
(213.8)
|
|
|
(232.3)
|
|
|
Consolidated Operating Revenues
|
$
|
962.7
|
|
|
$
|
1,010.4
|
|
|
$
|
2,568.2
|
|
|
$
|
2,880.2
|
|
|
Operating Income (Loss)
|
|
|
|
|
|
|
|
|
Gas Distribution Operations
|
$
|
1.7
|
|
|
$
|
379.0
|
|
|
$
|
80.2
|
|
|
$
|
654.4
|
|
|
Electric Operations
|
86.9
|
|
|
85.7
|
|
|
165.4
|
|
|
180.7
|
|
|
Corporate and Other
|
3.1
|
|
|
(1.2)
|
|
|
(5.7)
|
|
|
2.6
|
|
|
Consolidated Operating Income
|
$
|
91.7
|
|
|
$
|
463.5
|
|
|
$
|
239.9
|
|
|
$
|
837.7
|
|
Table of Contents
ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS
NiSource Inc.
|
|
|
|
|
|
|
|
Index
|
Page
|
|
Executive Summary
|
|
|
Summary of Consolidated Financial Results
|
|
|
Results and Discussion of Segment Operations
|
|
|
Gas Distribution Operations
|
|
|
Electric Operations
|
|
|
Liquidity and Capital Resources
|
|
|
|
|
|
Market Risk Disclosures
|
|
|
Other Information
|
|
Table of Contents
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) analyzes our financial condition, results of operations and cash flows and those of our subsidiaries. It also includes management’s analysis of past financial results and certain potential factors that may affect future results, potential future risks and approaches that may be used to manage those risks. See "Note regarding forward-looking statements" at the beginning of this report for a list of factors that may cause results to differ materially.
Management’s Discussion is designed to provide an understanding of our operations and financial performance and should be read in conjunction with our Annual Report on Form 10-K for the fiscal year ended December 31, 2019.
We are an energy holding company under the Public Utility Holding Company Act of 2005 whose subsidiaries are fully regulated natural gas and electric utility companies serving customers in seven states. We generate substantially all of our operating income through these rate-regulated businesses, which are summarized for financial reporting purposes into two primary reportable segments: Gas Distribution Operations and Electric Operations.
Refer to the “Business” section of our Annual Report on Form 10-K for the fiscal year ended December 31, 2019 for further discussion of our regulated utility business segments.
Our goal is to develop strategies that benefit all stakeholders as we address changing customer conservation patterns, develop more contemporary pricing structures and embark on long-term investment programs. These strategies are intended to improve reliability and safety, enhance customer service and reduce emissions while generating sustainable returns. Additionally, we continue to pursue regulatory and legislative initiatives that will allow residential customers not currently on our system to obtain gas service in a cost effective manner. Refer also to the discussion of Electric Supply within our Electric Operations discussion for additional information on our long term electric generation strategy.
COVID-19: During the first quarter of 2020, the United States and countries around the globe were impacted by the outbreak of COVID-19. On March 11, 2020, the WHO declared the outbreak of COVID-19 to be a global pandemic. In response to this declaration and the rapid spread of COVID-19 within the United States, federal, state and local governments throughout the country have imposed varying degrees of restrictions on social and commercial activity to promote social distancing in an effort to slow the spread of the illness. These measures have had and continue to have a significant adverse impact upon many sectors of the economy.
We provide essential natural gas and electric services. The safety of our employees and customers, while providing these essential services during the COVID-19 pandemic, is paramount. Since March, 2020, we have taken a proactive, coordinated approach intended to prevent, mitigate and respond to COVID-19 by utilizing our Incident Command System (ICS), which 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. This includes, without limitation, assessing COVID-19 cases, conditions and mandates by location, utilizing employee and customer health and mitigation plans, utilizing technology to maximize work-from-home capabilities, securing appropriate personal protective equipment and cleaning facilities, coordinating customer, employee and stakeholder messaging, and monitoring impacts to supply chain and contractor networks. We are also monitoring guidance from the Centers for Disease Control (CDC), as well as local, state and federal agencies.
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, temperature checks and more frequent cleaning of equipment and facilities. We have also implemented work-from-home policies. We have minimized non-essential work that requires an employee to enter a customer premise and limiting company vehicle occupancy to one person. We continue to employ physical and cyber-security measures to ensure that our operational and support systems remain functional. Our actions to date have mitigated the impact of COVID-19 on our employees. We have had a limited amount of known COVID cases within our company. We will continue to follow CDC guidance and implement safety measures to ensure our employees and customer safety during this pandemic.
Table of Contents
ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (continued)
NiSource Inc.
We have suspended shut-offs for non-payment and late payment charges in response to the COVID-19 pandemic. These suspensions apply to residential, commercial and industrial customers and are expected to remain in effect though the third or fourth quarters of 2020, depending on requirements provided by state regulatory commissions. In addition, we are offering more flexible payment plans to customers impacted or experiencing hardship as a result of COVID-19. The CARES Act was enacted on March 27, 2020 and provides monetary-relief and financial aid to individuals, business, nonprofits, states and municipalities. We are continuing to promote multiple resources available to customers including benefits from the CARES Act, such as additional funding for both the Low-Income Home Energy Assistance Program and the Community Services Block Grant to help support income-qualified customers. We are sharing energy efficiency tips to help customers save energy at home and promoting our budget plan program, which allows customers to pay about the same amount each month.
We continue to have interactions with the state regulatory commissions for each of our operating companies regarding COVID-19. These interactions primarily focus on steps we are taking to safely maintain essential services, including waivers of certain regulatory requirements, where needed, to allow for continued safe operations. We are also engaging regulators to address the short-term and long-term economic impact COVID-19 has, and may continue to have, on our customers and our operations. Regulatory deferrals have been allowed by the state regulatory commissions in Maryland, Ohio, Virginia, Pennsylvania and Indiana. For information on the impact of COVID-19 regulatory filings, see Note 10, “Regulatory Matters,” in the Notes to Condensed Consolidated Financial Statements (unaudited).
COVID-19 has resulted in new federal and state laws. Under the provisions of the CARES Act, we have deferred payroll tax payments of approximately $9.9 million through June 30, 2020. We believe the deferral of payroll tax payments could provide a cash flow benefit by delaying about $30.0 million of 2020 payroll tax payments, of which 50% would be due at the end of 2021 and the remaining 50% would be due at the end of 2022. Given the recent enactment of the CARES Act and additional guidance issued by the IRS, we are currently evaluating the impact of the employer payroll tax credits and other potentially applicable provisions. For information on the impact of the CARES Act on Income Taxes, see Note 15, "Income Taxes," in the Notes to Condensed Consolidated Financial Statements (unaudited).
COVID-19 has impacted our results of operation in the first half of 2020. As a result of COVID-19, we have experienced, and expect to continue to experience, changes in the demand for gas and electric. For the six months ended June 30, 2020, usage was lower compared to same period in 2019, with approximately $17.8 million in lower usage revenue primarily attributable to lower gas and electric commercial and industrial demand resulting from COVID-19, partially offset by higher residential demand primarily attributable to COVID-19 that resulted in higher residential usage revenue of approximately $6.9 million. Also, for the six months ended June 30, 2020, revenue from late payment and reconnections fees were lower compared to the same period in 2019, with approximately $3.8 million in reduced revenue primarily attributable to COVID-19. During the six months ended June 30, 2020, we incurred approximately $10.8 million in expenses for personal protective equipment and other COVID-19 related services and supplies, as well as higher bad debt expense in comparison to the same period in 2019 of approximately $7.2 million primarily resulting from economic conditions, as well as the suspension of shut-offs for non-payment. We did experience lower cash flows from operations in the second quarter of 2020 in comparison to the second quarter 2019; however, we believe we have sufficient liquidity for the next 12 to 24 months as a result of the refinancing of our $850 million term loan on April 1, 2020, the issuance of $1.0 billion notes on April 13, 2020, the anticipated cash proceeds from the sale of the Massachusetts Business that we expect to close by the end of the third quarter of 2020 or shortly thereafter, the available capacity under our short-term revolving credit facility and accounts receivable securitization facilities, and our ability to access capital markets. We have reduced our expected 2020 capital investments by $145 million to conserve cash. There are no other changes to our capital construction programs or our renewable generation projects. While we have not experienced any significant issues in our supply chain, we are actively managing the materials, supplies, and contract services for our generation, transmission, distribution, and customer services functions.
We are continuously evaluating and monitoring the impact of COVID-19 on our operating results and liquidity. We believe our future operating results and liquidity will be impacted by COVID-19. Such impact of COVID-19 includes, but is not limited to:
•Lower revenue and cash flow during the second half of 2020, in comparison to the second half of 2019, resulting from the decrease in commercial and industrial gas and electric demand as businesses comply with re-opening plans in each state and as businesses experience negative economic impact from COVID-19, potentially offset by higher residential demand.
•Lower revenue and cash flow during the second half of 2020, in comparison to the second half of 2019, due to the continuing suspension of late payment and reconnection fees.
•A decline in revenue in 2021 due to an increase in customer attrition rates, as well as lower revenue growth if customer additions slow due to a prolonged economic downturn.
Table of Contents
ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (continued)
NiSource Inc.
•A continued increase in bad debt and decrease in cash flows in the second half of 2020 and into 2021 resulting from the suspension of shut-offs and the inability of our customers to pay for their gas and electric service due to job loss or other factors, partially offset by regulatory deferral.
•A continued delay in cash flows in 2020 as customers utilized the more flexible payment plans.
•A sustained increase in COVID-19 related materials, supplies and contract services costs during the second half of 2020, partially offset by any allowed regulatory deferral of incremental COVID-19 related expenses, a reduction in non-safety related employee and administrative expenses, and efforts to address dis-synergies and improve efficiencies.
•An increase in internal labor costs from higher overtime costs in the second half of 2020.
•The impact of the employer payroll tax credit and payroll tax payment deferral under the CARES Act. As discussed above, we believe the deferral of payroll tax payments could provide a cash flow benefit in 2020 by delaying about $30.0 million of payroll tax payments. The IRS has issued additional guidance related to the employer tax credit as recently as mid-June, and we are currently evaluating the impact of the employer payroll tax credits.
In addition, we are monitoring the following areas that could impact our operating results and liquidity:
•A delay in cash flows in the event that the sale of the Massachusetts Business does not close by the end of the third quarter of 2020 or shortly thereafter, which could impact our liquidity.
•Future volatility in the capital and credit markets that could impact our liquidity by limiting our access to capital or increasing the cost of capital.
•A deterioration in market conditions that could reduce our reporting units' fair values below their carrying values, resulting in future goodwill impairment charges. Currently, we have no impairments related to goodwill or long lived assets.
•A potential increase in future pension expense and pension funding requirements due to the degradation of interest rates and capital market conditions. Any increase in pension expense would not be determined until the year-end remeasurement or at an interim remeasurement if triggered by higher than expected lump sum payments. We expect to trigger an interim remeasurement during the second half of 2020 due to higher than expected lump sum payments.
•Potential delays in capital construction projects, including the impact on our renewable generation projects.
•A potential reduction in labor availability and productivity due to the health impact COVID-19 could have on our employees and contractors.
•The potential for delayed state regulatory filings, regulatory approvals and recovery of invested capital.
•The impact of any new state regulatory actions and federal laws.
This is an evolving situation, and we cannot predict the extent or duration of the outbreak, or the total effects on the global, national or local economy, or our operations or financial results. We will continue to monitor developments affecting our workforce, customers, suppliers and operations and take additional measures as needed in an effort to help mitigate the impacts of the COVID-19 pandemic on our company and in our communities.
Greater Lawrence Incident: The Greater Lawrence Incident occurred on September 13, 2018. The following table summarizes expenses incurred and insurance recoveries recorded since the Greater Lawrence Incident. The amounts set forth in the table below do not include the estimated capital cost of the pipeline replacement described below and as set forth in Note 19- D, "Other Matters - Greater Lawrence Pipeline Replacement," in the Notes to Condensed Consolidated Financial Statements (unaudited).
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total Costs Incurred through
|
|
|
|
Costs Incurred during the Three Months Ended
|
Costs Incurred during the Six Months Ended
|
|
|
|
|
(in millions)
|
December 31, 2019
|
|
|
|
June 30, 2020
|
|
|
|
Incident to Date
|
|
Third-party claims
|
$
|
1,041
|
|
|
|
|
$
|
(2)
|
|
$
|
(2)
|
|
|
|
$
|
1,039
|
|
|
Other incident-related costs
|
420
|
|
|
|
|
7
|
|
16
|
|
|
|
436
|
|
|
Total
|
1,461
|
|
|
|
|
5
|
|
14
|
|
|
|
1,475
|
|
|
Insurance recoveries recorded
|
(800)
|
|
|
|
|
—
|
|
—
|
|
|
|
(800)
|
|
|
Total costs incurred
|
$
|
661
|
|
|
|
|
$
|
5
|
|
$
|
14
|
|
|
|
$
|
675
|
|
Table of Contents
ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (continued)
NiSource Inc.
Inclusive of the $1,039 million of third-party claims and fines, penalties and settlements associated with government investigations recorded incident to date, we estimate that total costs related to third-party claims and fines, penalties and settlements associated with government investigations as set forth in Note 19, "Other Commitments and Contingencies - B. Legal Proceedings," will range from $1,039 million to $1,055 million, depending on the number, nature, final outcome and value of third-party claims and the final outcome of government investigations. These costs do not include costs of certain third-party claims and fines, penalties or settlements with government investigations that we are not able to estimate. These costs also do not include the payment in lieu of penalties, which is set forth in Note 7, "Assets and Liabilities Held for Sale."
We expect to incur a total of $445 million to $455 million in other incident-related costs, inclusive of the $436 million recorded for the incident to date, as set forth in Note 19, "Other Commitments and Contingencies - D. Other Matters - Greater Lawrence Incident Restoration."
The process for estimating costs associated with third-party claims and fines, penalties and settlements associated with government investigations relating to the Greater Lawrence Incident requires management to exercise significant judgment based on a number of assumptions and subjective factors. As more information becomes known, including additional information regarding ongoing investigations, management's estimates and assumptions regarding the financial impact of the Greater Lawrence Incident may change.
The aggregate amount of third-party liability insurance coverage available for losses arising from the Greater Lawrence Incident is $800 million. We have collected the entire $800 million.
We have invested approximately $258 million of capital spend for the pipeline replacement; this work was completed in 2019. We maintain property insurance for gas pipelines and other applicable property. Columbia of Massachusetts has filed a proof of loss with its property insurer for the full cost of the pipeline replacement. In January 2020, we filed a lawsuit against the property insurer, seeking payment of our property claim. We are currently unable to predict the timing or amount of any insurance recovery under the property policy. This pipeline replacement cost is part of the Massachusetts Business that is classified as held for sale at June 30, 2020. The assets and liabilities of the Massachusetts Business have been recorded at fair value, less costs to sell, which has resulted in a loss being recorded as of June 30, 2020. See Note 7, "Assets and Liabilities Held for Sale," in the Notes to Condensed Consolidated Financial Statements (unaudited) for additional information.
Refer to Note 19-B and D, "Legal Proceedings" and "Other Matters," in the Notes to Condensed Consolidated Financial Statements (unaudited), "Summary of Consolidated Financial Results," "Results and Discussion of Segment Operation - Gas Distribution Operations," and "Liquidity and Capital Resources" in this Management's Discussion for additional information related to the Greater Lawrence Incident.
Columbia of Massachusetts Asset Sale: On February 26, 2020, NiSource and Columbia of Massachusetts entered into an Asset Purchase Agreement with Eversource. Upon the terms and subject to the conditions set forth in the Asset Purchase Agreement, we have agreed to sell the Massachusetts Business to Eversource for a purchase price of $1,100 million in cash, subject to adjustment. For additional information, see Note 7, "Assets and Liabilities Held for Sale," in the Notes to Condensed Consolidated Financial Statements (unaudited).
Strategic Initiative: We have launched a multi-year, enterprise-wide strategic initiative to better leverage our current scale, improve our cost structure and drive long-term capabilities. This initiative is expected to support continued substantial capital investments in our long-term safety and modernization programs, as well as our electric generation strategy, providing value to both customers and investors. The repositioning of executive leadership roles and responsibilities in May 2020, the strategic initiative, and a voluntary separation program for certain employees, which commenced on August 5, 2020, are the first steps in a process designed to ensure that we are best positioned to support our enhanced focus on safety, operational excellence and customer value.
Table of Contents
ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (continued)
NiSource Inc.
Summary of Consolidated Financial Results
A summary of our consolidated financial results for the three and six months ended June 30, 2020 and 2019 are presented below:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended June 30,
|
|
|
|
|
|
Six Months Ended June 30,
|
|
|
|
|
|
(in millions, except per share amounts)
|
2020
|
|
2019
|
|
2020 vs. 2019
|
|
2020
|
|
2019
|
|
2020 vs. 2019
|
|
Operating Revenues
|
$
|
962.7
|
|
|
$
|
1,010.4
|
|
|
$
|
(47.7)
|
|
|
$
|
2,568.2
|
|
|
$
|
2,880.2
|
|
|
$
|
(312.0)
|
|
|
Operating Expenses
|
|
|
|
|
|
|
|
|
|
|
|
|
Cost of sales (excluding depreciation and amortization)
|
188.4
|
|
|
253.5
|
|
|
(65.1)
|
|
|
650.8
|
|
|
933.8
|
|
|
(283.0)
|
|
|
Other Operating Expenses
|
682.6
|
|
|
293.4
|
|
|
389.2
|
|
|
1,677.5
|
|
|
1,108.7
|
|
|
568.8
|
|
|
Total Operating Expenses
|
871.0
|
|
|
546.9
|
|
|
324.1
|
|
|
2,328.3
|
|
|
2,042.5
|
|
|
285.8
|
|
|
Operating Income
|
91.7
|
|
|
463.5
|
|
|
(371.8)
|
|
|
239.9
|
|
|
837.7
|
|
|
(597.8)
|
|
|
Total Other Deductions, net
|
(90.5)
|
|
|
(94.4)
|
|
|
3.9
|
|
|
(178.0)
|
|
|
(190.7)
|
|
|
12.7
|
|
|
Income Taxes
|
5.9
|
|
|
72.2
|
|
|
(66.3)
|
|
|
(9.0)
|
|
|
131.2
|
|
|
(140.2)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net Income (Loss)
|
(4.7)
|
|
|
296.9
|
|
|
(301.6)
|
|
|
70.9
|
|
|
515.8
|
|
|
(444.9)
|
|
|
Preferred dividends
|
(13.8)
|
|
|
(13.8)
|
|
|
—
|
|
|
(27.6)
|
|
|
(27.6)
|
|
|
—
|
|
|
Net Income (Loss) Available to Common Shareholders
|
(18.5)
|
|
|
283.1
|
|
|
(301.6)
|
|
|
43.3
|
|
|
488.2
|
|
|
(444.9)
|
|
|
Basic Earnings (Loss) Per Share
|
$
|
(0.05)
|
|
|
$
|
0.76
|
|
|
$
|
(0.81)
|
|
|
$
|
0.11
|
|
|
$
|
1.31
|
|
|
$
|
(1.20)
|
|
|
Basic Average Common Shares Outstanding
|
383.5
|
|
|
373.9
|
|
|
9.6
|
|
|
383.3
|
|
|
373.6
|
|
|
9.7
|
|
Our operations are affected by the cost of sales. Cost of sales (excluding depreciation and amortization) for the Gas Distribution Operations segment is principally comprised of the cost of natural gas used while providing transportation and distribution services to customers. Cost of sales (excluding depreciation and amortization) for the Electric Operations segment is comprised of the cost of coal, related handling costs, natural gas purchased for the internal generation of electricity at NIPSCO and the cost of power purchased from third-party generators of electricity. The majority of the cost of sales (excluding depreciation and amortization) 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 loss available to common shareholders of $18.5 million, or $0.05 per basic share for the three months ended June 30, 2020, compared to net income available to common shareholders of $283.1 million, or $0.76 per basic share for the same period in 2019. The decrease in income available to common shareholders during the second quarter of 2020 was primarily due to higher operating expenses due to insurance recoveries recorded in 2019, net of third-party claims and other costs, related to the Greater Lawrence Incident and an increase in the loss recorded for the classification as held for sale of the Massachusetts Business (see Note 7, "Assets and Liabilities Held for Sale," in the Notes to the Condensed Consolidated Financial Statements (unaudited) for additional information). In addition, COVID-19 impacted our results of operation as we have experienced unfavorable changes in commercial and industrial demand for Electric Operations and unfavorable changes in industrial demand for Gas Distribution Operations, as well as incremental COVID-19 related expenses. These increases in expense and decreases in demand are partially offset by lower income taxes in the second quarter (see "Income Taxes" below).
For the six months ended June 30, 2020, we reported net income available to common shareholders of $43.3 million, or $0.11 per basic share compared to net income available to common shareholders of $488.2 million, or $1.31 per basic share for the same period in 2019. The drivers for this decrease were consistent with that of the quarter-to-date period, with the addition of lower gas distribution operating revenues due to the effects of warmer weather in 2020.
Operating Income
For the three months ended June 30, 2020, we reported operating income of $91.7 million compared to operating income of $463.5 million for the same period in 2019. The decrease in operating income was primarily due to higher operating expenses due to insurance recoveries recorded in 2019, net of third-party claims and other costs, related to the Greater Lawrence Incident and the loss recorded for the classification as held for sale of the Massachusetts Business (see Note 7, "Assets and Liabilities Held for Sale," in the Notes to the Condensed Consolidated Financial Statements (unaudited) for additional information). In addition, COVID-19 impacted our results of operation as we have experienced unfavorable changes in the demand for gas and electric and incremental COVID-19 related expenses.
Table of Contents
ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (continued)
NiSource Inc.
For the six months ended June 30, 2020, we reported operating income of $239.9 million compared to operating income of $837.7 million for the same period in 2019. The drivers for this decrease were consistent with that of the quarter-to-date period, with the addition of lower gas distribution operating revenues due to the effects of warmer weather in 2020.
Other Deductions, net
Other deductions, net reduced income by $90.5 million in the second quarter of 2020 compared to a reduction in income of $94.4 million in the prior year. This change is primarily due to lower non-service pension costs driven by a decrease in the pension benefit obligations.
Other deductions, net reduced income by $178.0 million during the six months ended June 30, 2020 compared to a reduction in income of $190.7 million in the prior year. The drivers for this change were consistent with that of the quarter-to-date period.
Income Taxes
For the three and six months ended June 30, 2020, the decrease in income tax expense from 2019 to 2020 is primarily attributable to lower pre-tax income, increased amortization of excess deferred federal income tax liabilities, as specified in the TCJA, discrete items primarily related to the pre–tax book loss recorded for the classification as held for sale of the Massachusetts Business, adjusted for the non-deductible payment in lieu of penalties, tax effected at statutory tax rates.
Refer to Note 15, "Income Taxes," in the Notes to Condensed Consolidated Financial Statements (unaudited) for information on income taxes and the change in the effective tax rate.
Capital Investment
For the six months ended June 30, 2020, we invested $819.3 million in capital expenditures across our gas and electric utilities. These expenditures were primarily aimed at furthering the safety and reliability of our gas distribution system, system modernization projects and maintaining our existing electric generation fleet.
We continue to execute on an estimated $30 billion in total projected long-term regulated utility infrastructure investments and expect to invest a total of approximately $1.7 to $1.8 billion in capital during 2020 as we continue to focus on growth, safety and modernization projects across our operating area.
Liquidity
A primary focus of ours is to ensure the availability of adequate financing to fund our ongoing safety and infrastructure investment programs, which typically involves the issuance of debt and/or equity. In addition, expenses related to the Greater Lawrence Incident have exceeded the total amount of insurance coverage available under our policies. During 2020, we took certain actions to enhance our liquidity. On April 1, 2020, we terminated and repaid in full our existing $850.0 million term loan agreement and entered into a new $850.0 million term loan agreement that matures March 31, 2021. Also, on April 13, 2020, we completed the issuance and sale of $1.0 billion of senior unsecured notes resulting in approximately $987.8 million of net proceeds.
Through income generated from operating activities, amounts available under our short-term revolving credit facility, commercial paper program, accounts receivable securitization facilities, term loan borrowings, long-term debt agreements, our ability to access the capital markets, and the expected proceeds from the potential sale of the Massachusetts Business (see Note 7, "Assets and Liabilities Held for Sale," in the Notes to the Condensed Consolidated Financial Statements (unaudited) for additional information), we believe we have adequate capital available to fund our operating activities, capital expenditures, the effects of the Greater Lawrence Incident and the effects of COVID-19 for the next 12 to 24 months. As of June 30, 2020 and December 31, 2019, we had $1,982.0 million and $1,409.1 million, respectively, of net liquidity available, consisting of cash and available capacity under credit facilities.
These factors and other impacts to the financial results are discussed in more detail within the following discussions of “Results and Discussion of Segment Operations” and “Liquidity and Capital Resources.” See the COVID-19 discussion in the introduction to the "Executive Summary" for discussion regarding the liquidity impact from COVID-19.
Regulatory Developments
During the quarter ended June 30, 2020, we continued to move forward on core infrastructure and environmental investment programs supported by complementary regulatory and customer initiatives across all seven states of our operating area. We also continue to monitor COVID-19 related regulatory impact. Refer to Note 10, "Regulatory Matters" and Note 19-D "Other Matters," in the Notes to Condensed Consolidated Financial Statements (unaudited) for a complete discussion of key regulatory developments that have transpired during 2020.
Table of Contents
ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (continued)
NiSource Inc.
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.
Table of Contents
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, 2020 and 2019 are presented below:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended June 30,
|
|
|
|
|
|
Six Months Ended June 30,
|
|
|
|
|
|
(in millions)
|
2020
|
|
2019
|
|
2020 vs. 2019
|
|
2020
|
|
2019
|
|
2020 vs. 2019
|
|
Operating Revenues
|
$
|
609.2
|
|
|
$
|
607.1
|
|
|
$
|
2.1
|
|
|
$
|
1,840.2
|
|
|
$
|
2,049.2
|
|
|
$
|
(209.0)
|
|
|
Operating Expenses
|
|
|
|
|
|
|
|
|
|
|
|
|
Cost of sales (excluding depreciation and amortization)
|
119.2
|
|
|
136.7
|
|
|
(17.5)
|
|
|
496.6
|
|
|
686.8
|
|
|
(190.2)
|
|
|
Operation and maintenance
|
263.1
|
|
|
(60.3)
|
|
|
323.4
|
|
|
593.2
|
|
|
391.0
|
|
|
202.2
|
|
|
Depreciation and amortization
|
86.8
|
|
|
99.4
|
|
|
(12.6)
|
|
|
183.3
|
|
|
196.8
|
|
|
(13.5)
|
|
Loss on classification as held for sale
|
84.4
|
|
|
—
|
|
|
84.4
|
|
|
364.6
|
|
|
—
|
|
|
364.6
|
|
|
Gain on sale of assets
|
—
|
|
|
(0.1)
|
|
|
0.1
|
|
|
—
|
|
|
(0.1)
|
|
|
0.1
|
|
|
Other taxes
|
54.0
|
|
|
52.4
|
|
|
1.6
|
|
|
122.3
|
|
|
120.3
|
|
|
2.0
|
|
|
Total Operating Expenses
|
607.5
|
|
|
228.1
|
|
|
379.4
|
|
|
1,760.0
|
|
|
1,394.8
|
|
|
365.2
|
|
|
Operating Income
|
$
|
1.7
|
|
|
$
|
379.0
|
|
|
$
|
(377.3)
|
|
|
$
|
80.2
|
|
|
$
|
654.4
|
|
|
$
|
(574.2)
|
|
|
Revenues
|
|
|
|
|
|
|
|
|
|
|
|
|
Residential
|
$
|
410.6
|
|
|
$
|
379.6
|
|
|
$
|
31.0
|
|
|
$
|
1,233.9
|
|
|
$
|
1,355.6
|
|
|
$
|
(121.7)
|
|
|
Commercial
|
124.1
|
|
|
122.7
|
|
|
1.4
|
|
|
398.1
|
|
|
454.3
|
|
|
(56.2)
|
|
|
Industrial
|
48.8
|
|
|
53.0
|
|
|
(4.2)
|
|
|
123.3
|
|
|
136.0
|
|
|
(12.7)
|
|
|
Off-System
|
8.0
|
|
|
23.4
|
|
|
(15.4)
|
|
|
26.7
|
|
|
43.5
|
|
|
(16.8)
|
|
|
Other
|
17.7
|
|
|
28.4
|
|
|
(10.7)
|
|
|
58.2
|
|
|
59.8
|
|
|
(1.6)
|
|
|
Total
|
$
|
609.2
|
|
|
$
|
607.1
|
|
|
$
|
2.1
|
|
|
$
|
1,840.2
|
|
|
$
|
2,049.2
|
|
|
$
|
(209.0)
|
|
|
Sales and Transportation (MMDth)
|
|
|
|
|
|
|
|
|
|
|
|
|
Residential
|
39.8
|
|
|
32.2
|
|
|
7.6
|
|
|
158.3
|
|
|
172.9
|
|
|
(14.6)
|
|
|
Commercial
|
28.4
|
|
|
28.4
|
|
|
—
|
|
|
102.1
|
|
|
114.4
|
|
|
(12.3)
|
|
|
Industrial
|
124.2
|
|
|
125.4
|
|
|
(1.2)
|
|
|
271.0
|
|
|
273.5
|
|
|
(2.5)
|
|
|
Off-System
|
4.1
|
|
|
8.9
|
|
|
(4.8)
|
|
|
15.3
|
|
|
16.1
|
|
|
(0.8)
|
|
|
Other
|
—
|
|
|
0.1
|
|
|
(0.1)
|
|
|
0.2
|
|
|
0.3
|
|
|
(0.1)
|
|
|
Total
|
196.5
|
|
|
195.0
|
|
|
1.5
|
|
|
546.9
|
|
|
577.2
|
|
|
(30.3)
|
|
|
Heating Degree Days
|
728
|
|
|
499
|
|
|
229
|
|
|
3,168
|
|
|
3,396
|
|
|
(228)
|
|
|
Normal Heating Degree Days
|
563
|
|
|
563
|
|
|
—
|
|
|
3,460
|
|
|
3,427
|
|
|
33
|
|
|
% Colder (Warmer) than Normal
|
29
|
%
|
|
(11)
|
%
|
|
|
|
(8)
|
%
|
|
(1)
|
%
|
|
|
|
Gas Distribution Customers
|
|
|
|
|
|
|
|
|
|
|
|
|
Residential
|
|
|
|
|
|
|
3,237,131
|
|
|
3,180,255
|
|
|
56,876
|
|
|
Commercial
|
|
|
|
|
|
|
282,482
|
|
|
279,450
|
|
|
3,032
|
|
|
Industrial
|
|
|
|
|
|
|
5,983
|
|
|
6,078
|
|
|
(95)
|
|
|
Other
|
|
|
|
|
|
|
3
|
|
|
3
|
|
|
—
|
|
|
Total
|
|
|
|
|
|
|
3,525,599
|
|
|
3,465,786
|
|
|
59,813
|
|
Cost of sales (excluding depreciation and amortization) for the Gas Distribution Operations segment is principally comprised of the cost of natural gas used while providing transportation and distribution services to customers. The cost of sales (excluding depreciation and amortization) are tracked costs that are passed through directly to the customer resulting in an equal and offsetting amount reflected in operating revenue. In addition, 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. Therefore, increases in these tracked operating expenses are offset by increases in operating revenues and have essentially no impact on net income.
Table of Contents
ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (continued)
NiSource Inc.
Gas Distribution Operations
Three Months Ended June 30, 2020 vs. June 30, 2019 Operating Income
For the three months ended June 30, 2020, Gas Distribution Operations reported operating income of $1.7 million, a decrease of $377.3 million from the comparable 2019 period.
Operating revenues for the three months ended June 30, 2020 were $609.2 million, an increase of $2.1 million from the same period in 2019. The change in operating revenues was primarily driven by:
•New rates from base rate proceedings, infrastructure replacement programs and Columbia of Ohio's CEP of $12.1 million.
•Unfavorable adjustments in 2019 to the revenue reserve for the probable future refund of certain collections from customers as a result of the lower income tax rate from the TCJA of $5.1 million.
•The effects of customer growth of $5.0 million.
•Higher revenues from the effects of colder weather in 2020 of $4.4 million.
•Higher regulatory, tax and depreciation trackers, which are offset in operating expense, of $2.8 million.
•The effects of increased residential usage primarily related to COVID-19 of $0.7 million.
Partially offset by:
•Lower cost of sales (excluding depreciation and amortization) billed to customers, which is offset in operating expense, of $17.5 million.
•The effects of decreased industrial usage primarily related to COVID-19 of $4.7 million.
•The effects of decreased late payment and reconnection fees primarily related to COVID-19 of $3.0 million.
•Lower revenue from Columbia of Ohio's DSM incentive program of $1.1 million.
Operating expenses were $379.4 million higher for the three months ended June 30, 2020 compared to the same period in 2019. This change was primarily driven by:
•Insurance recoveries recorded in 2019, net of third-party claims and other costs, related to the Greater Lawrence Incident of $337.0 million.
•Loss on classification as held for sale related to the Massachusetts Business of $84.4 million.
•Increased bad debt expense primarily related to COVID-19 of $6.2 million.
•Increased expenses primarily due to the impact of COVID-19 related materials & supplies, outside services, and sequestration expenses of $5.2 million.
•Higher regulatory, tax and depreciation trackers, which are offset in operating revenue, of $2.8 million.
Partially offset by:
•Lower employee and administrative expenses of $22.4 million.
•Lower cost of sales (excluding depreciation and amortization) billed to customers, which is offset in operating revenue, of $17.5 million.
•Lower depreciation and amortization of $13.0 million due to a $15.0 million decrease in depreciation and amortization as a result of classifying the Massachusetts Business as held for sale, offset by a $2.0 million increase in depreciation and amortization primarily due to higher capital expenditures placed in service.
Six Months Ended June 30, 2020 vs. June 30, 2019 Operating Income
For the six months ended June 30, 2020, Gas Distribution Operations reported operating income of $80.2 million, a decrease of $574.2 million from the comparable 2019 period.
Operating revenues for the six months ended June 30, 2020 were $1,840.2 million, a decrease of $209.0 million from the same period in 2019. The change in operating revenues was primarily driven by:
•Lower cost of sales (excluding depreciation and amortization) billed to customers, which is offset in operating expense, of $190.2 million.
•Lower revenues from the effects of warmer weather in 2020 of $31.7 million.
•Lower regulatory, tax and depreciation trackers, which are offset in operating expense, of $11.1 million.
Table of Contents
ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (continued)
NiSource Inc.
Gas Distribution Operations
•The effects of decreased industrial usage primarily related to COVID-19 of $4.7 million.
•The effects of decreased late payment and reconnection fees primarily related to COVID-19 of $3.0 million.
Partially Offset by:
•New rates from base rate proceedings, infrastructure replacement programs and Columbia of Ohio's CEP of $26.8 million.
•The effects of customer growth of $9.4 million.
•The effects of increased residential usage primarily related to COVID-19 of $0.7 million.
Operating expenses were $365.2 million higher for the six months ended June 30, 2020 compared to the same period in 2019. This change was primarily driven by:
•Loss on classification as held for sale related to the Massachusetts Business of $364.6 million.
•Insurance recoveries recorded in 2019, net of third-party claims and other costs, related to the Greater Lawrence Incident of $209.8 million.
•Increased bad debt expense primarily related to COVID-19 of $6.2 million.
•Increased expenses primarily due to the impact of COVID-19 related materials & supplies, outside services, and sequestration expenses of $6.1 million.
•Increased property taxes of $5.9 million due to higher capital expenditures placed in service.
Partially offset by:
•Lower cost of sales (excluding depreciation and amortization) billed to customers, which is offset in operating revenue, of $190.2 million.
•Lower depreciation and amortization of $13.4 million due to a $20.0 million decrease in depreciation and amortization as a result of classifying the Massachusetts Business as held for sale, offset by a $6.6 million increase in depreciation and amortization primarily due to higher capital expenditures placed in service.
•Lower regulatory, tax and depreciation trackers, which are offset in operating revenue, of $11.1 million.
•Lower employee and administrative expenses of $10.3 million.
Weather
In general, we calculate the weather-related revenue variance based on changing customer demand driven by weather variance from normal heating degree days. Our composite heating degree days reported do not directly correlate to the weather-related dollar impact on the results of Gas Distribution Operations. Heating degree days experienced during different times of the year or in different operating locations may have more or less impact on volume and dollars depending on when and where they occur. When the detailed results are combined for reporting, there may be weather-related dollar impacts on operations when there is not an apparent or significant change in our aggregated composite heating degree day comparison.
Weather in the Gas Distribution Operations service territories for the second quarter of 2020 was about 29% colder than normal and about 46% colder than 2019, leading to increased operating revenues of $4.4 million for the quarter ended June 30, 2020 compared to the same period in 2019.
Weather in the Gas Distribution Operations service territories for the six months ended June 30, 2020 was about 8% warmer than normal and about 7% warmer than 2019, leading to decreased operating revenues of $31.7 million for the six months ended June 30, 2020 compared to the same period in 2019.
Throughput
Total volumes sold and transported for the three months ended June 30, 2020 were 196.5 MMDth, compared to 195.0 MMDth for the same period in 2019. This increase is primarily attributable to colder weather in 2020 compared to 2019, offset by decreased usage by industrial customers primarily due to COVID-19.
Total volumes sold and transported for the six months ended June 30, 2020 were 546.9 MMDth, compared to 577.2 MMDth for the same period in 2019. This decrease is primarily attributable to warmer weather in 2020 compared to 2019 and decreased usage by industrial customers primarily due to COVID-19.
Table of Contents
ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (continued)
NiSource Inc.
Gas Distribution Operations
Economic Conditions
All of our Gas Distribution Operations companies have state-approved recovery mechanisms that provide a means for full recovery of prudently incurred gas costs. Gas costs are treated as pass-through costs and have no impact on operating income recorded in the period. The gas costs included in revenues are matched with the gas cost expense recorded in the period and the difference is recorded on the Condensed Consolidated Balance Sheets (unaudited) as under-recovered or over-recovered gas cost to be included in future customer billings.
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.
COVID-19 has impacted many sectors of the economy. COVID-19 impacted our Gas Distribution Operations in the second quarter of 2020, as described above. We continue to monitor developments affecting our workforce, customers, suppliers and operations and will take additional measures as needed in an effort to help mitigate the impacts of the COVID-19 pandemic on our company and in our communities. See the COVID-19 discussion in the introduction to the "Executive Summary" for additional information.
Greater Lawrence Incident
Refer to Note 19-B, "Legal Proceedings," and D. "Other Matters," in the Notes to Condensed Consolidated Financial Statements (unaudited) and "Executive Summary" and "Liquidity and Capital Resources" in this Management's Discussion for additional information related to the Greater Lawrence Incident.
Columbia of Massachusetts Asset Sale
On February 26, 2020, we entered into an Asset Purchase Agreement with Eversource that provided for the sale of the Massachusetts Business to Eversource subject to terms and conditions set forth in the agreement. For additional information, see Note 7, "Assets and Liabilities Held for Sale," in the Notes to Condensed Consolidated Financial Statements (unaudited).
Table of Contents
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, 2020 and 2019 are presented below:
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Three Months Ended June 30,
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Six Months Ended June 30,
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(in millions)
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2020
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2019
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2020 vs. 2019
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2020
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2019
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2020 vs. 2019
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Operating Revenues
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356.4
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$
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406.6
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(50.2)
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733.9
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$
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837.6
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$
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(103.7)
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Operating Expenses
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Cost of sales (excluding depreciation and
amortization)
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69.2
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116.9
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(47.7)
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154.2
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247.0
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(92.8)
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Operation and maintenance
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108.0
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123.8
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(15.8)
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228.9
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245.5
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(16.6)
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Depreciation and amortization
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80.6
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69.2
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11.4
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159.5
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137.4
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22.1
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Other taxes
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11.7
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11.0
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0.7
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25.9
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27.0
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(1.1)
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Total Operating Expenses
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269.5
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320.9
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(51.4)
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568.5
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656.9
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(88.4)
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Operating Income
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$
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86.9
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|
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$
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85.7
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|
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$
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1.2
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|
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$
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165.4
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$
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180.7
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$
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(15.3)
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Revenues
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Residential
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$
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124.0
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$
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105.9
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$
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18.1
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$
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243.2
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$
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224.7
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$
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18.5
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Commercial
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109.8
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115.2
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(5.4)
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230.0
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234.5
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(4.5)
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Industrial
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86.5
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155.9
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(69.4)
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195.6
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319.4
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(123.8)
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Wholesale
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2.8
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|
|
2.8
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—
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6.0
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5.5
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|
0.5
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Other
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33.3
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|
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26.8
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|
|
6.5
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|
|
59.1
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|
|
53.5
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|
|
5.6
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Total
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$
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356.4
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$
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406.6
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$
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(50.2)
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$
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733.9
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$
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837.6
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$
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(103.7)
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Sales (Gigawatt Hours)
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|
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Residential
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834.0
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733.1
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|
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100.9
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1,589.5
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1,525.5
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64.0
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Commercial
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831.8
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891.0
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(59.2)
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1,710.5
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1,785.4
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(74.9)
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Industrial
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1,467.5
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2,164.5
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(697.0)
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3,538.6
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4,380.2
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(841.6)
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Wholesale
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4.9
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|
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1.1
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|
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3.8
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|
76.3
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7.6
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68.7
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Other
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21.5
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22.3
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(0.8)
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49.7
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56.8
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(7.1)
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Total
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3,159.7
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3,812.0
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(652.3)
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6,964.6
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7,755.5
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(790.9)
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Cooling Degree Days
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292
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|
|
223
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|
|
69
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|
|
292
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|
|
223
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|
69
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|
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Normal Cooling Degree Days
|
239
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|
|
245
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(6)
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239
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|
|
245
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(6)
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% Warmer (Colder) than Normal
|
22
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%
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(9)
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%
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22
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%
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(9)
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%
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Electric Customers
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|
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|
|
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Residential
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|
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417,251
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412,990
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|
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4,261
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|
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Commercial
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|
|
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|
|
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57,236
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|
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56,788
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|
|
448
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Industrial
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|
|
|
|
|
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2,164
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|
|
2,272
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|
(108)
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|
|
Wholesale
|
|
|
|
|
|
|
723
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|
|
732
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|
|
(9)
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|
|
Other
|
|
|
|
|
|
|
2
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|
|
3
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|
|
(1)
|
|
|
Total
|
|
|
|
|
|
|
477,376
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|
|
472,785
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|
|
4,591
|
|
Cost of sales (excluding depreciation and amortization) 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. The majority of the cost of sales (excluding depreciation and amortization) are tracked costs that are passed through directly to the customer resulting in an equal and offsetting amount reflected in operating revenue. In addition, 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. Therefore, increases in these tracked operating expenses are offset by increases in operating revenues and have essentially no impact on net income.
Table of Contents
ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (continued)
NiSource Inc.
Electric Operations
Three Months Ended June 30, 2020 vs. June 30, 2019 Operating Income
For the three months ended June 30, 2020, Electric Operations reported operating income of $86.9 million, an increase of $1.2 million from the comparable 2019 period.
Operating revenues for the three months ended June 30, 2020 were $356.4 million, a decrease of $50.2 million from the same period in 2019. The change in operating revenues was primarily driven by:
•Lower cost of sales (excluding depreciation and amortization) billed to customers, which is offset in operating expense, of $47.7 million.
•Lower regulatory and depreciation trackers, which are offset in operating expense, of $7.8 million.
•The effects of decreased commercial and industrial usage primarily related to COVID-19 of $13.1 million.
•The effects of decreased late payment and reconnection fees primarily related to COVID-19 of $0.8 million.
Partially offset by:
•New rates from the recent base rate proceeding and electric transmission projects of $6.8 million.
•The effects of increased residential usage primarily related to COVID-19 of $6.2 million.
•Decreased fuel handling costs of $3.2 million.
Operating expenses were $51.4 million lower for the three months ended June 30, 2020 compared to the same period in 2019. This change was primarily driven by:
•Lower cost of sales (excluding depreciation and amortization) billed to customers, which is offset in operating revenue, of $47.7 million.
•Lower outside service costs of $14.6 million primarily related to lower generation-related maintenance.
•Lower regulatory and depreciation trackers, which are offset in operating revenues, of $7.8 million.
•Lower employee and administrative costs of $7.0 million.
Partially offset by:
•Increased depreciation of $15.4 million primarily attributable to higher depreciation rates from the recent rate case proceeding.
•Increased expenses primarily due to the impact of COVID-19 related materials and supplies, outside services, and sequestration expenses of $4.3 million.
•Increased bad debt expense of $1.0 million primarily due to the impact of COVID-19.
Six Months Ended June 30, 2020 vs. June 30, 2019 Operating Income
For the six months ended June 30, 2020, Electric Operations reported operating income of $165.4 million, a decrease of $15.3 million from the comparable 2019 period.
Operating revenues for the six months ended June 30, 2020 were $733.9 million, a decrease of $103.7 million from the same period in 2019. The change in operating revenues was primarily driven by:
•Lower cost of sales (excluding depreciation and amortization) billed to customers, which is offset in operating expense, of $92.8 million.
•Lower regulatory and depreciation trackers, which are offset in operating expense, of $15.1 million.
•The effects of decreased commercial and industrial usage primarily related to COVID-19 of $13.1 million.
•The effects of decreased late payment and reconnection fees primarily related to COVID-19 of $0.8 million.
Partially offset by:
•New rates from the recent base rate proceeding and electric transmission projects of $8.3 million.
•The effects of increased residential usage primarily related to COVID-19 of $6.2 million.
Operating expenses were $88.4 million lower for the six months ended June 30, 2020 compared to the same period in 2019. This change was primarily driven by:
Table of Contents
ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (continued)
NiSource Inc.
Electric Operations
•Lower cost of sales (excluding depreciation and amortization) billed to customers, which is offset in operating revenue, of $92.8 million.
•Lower regulatory and depreciation trackers, which are offset in operating revenues, of $15.1 million.
•Lower outside services costs of $19.9 million primarily related to lower generation-related maintenance.
Partially offset by:
•Increased depreciation of $30.5 million primarily attributable to higher depreciation rates from the recent rate case proceeding.
•Increased expenses primarily due to the impact of COVID-19 related materials and supplies, outside services, and sequestration expenses of $4.7 million.
•Increased environmental costs of $3.6 million.
•Increased bad debt expense of $1.0 million primarily due to the impact of COVID-19.
Weather
In general, we calculate the weather-related revenue variance based on changing customer demand driven by weather variance from normal heating or cooling degree days. Our composite heating or cooling degree days reported do not directly correlate to the weather-related dollar impact on the results of Electric Operations. Heating or cooling degree days experienced during different times of the year may have more or less impact on volume and dollars depending on when they occur. When the detailed results are combined for reporting, there may be weather-related dollar impacts on operations when there is not an apparent or significant change in our aggregated composite heating or cooling degree day comparison.
Weather in the Electric Operations’ territories for the second quarter of 2020 was about 22% warmer than normal and about 31% warmer than in 2019, resulting in increased operating revenues of $2.2 million for the quarter ended June 30, 2020 compared to the same period in 2019.
Weather in the Electric Operations’ territories for the six months ended June 30, 2020 was about 22% warmer than normal and about 31% warmer than in 2019, resulting in increased operating revenues of $1.1 million for the six months ended June 30, 2020 compared to the same period in 2019.
Sales
Electric Operations sales for the second quarter of 2020 were 3,159.7 GWh, a decrease of 652.3 GWh compared to the same period in 2019. This decrease was primarily attributable to decreased usage by industrial and commercial customers due to COVID-19 and higher self-generation by industrial customers, partially offset by increased usage by residential customers primarily due to COVID-19.
Electric Operations sales for the six months ended June 30, 2020 were 6,964.6 GWh, a decrease of 790.9 GWh compared to the same period in 2019. This decrease was primarily attributable to decreased usage by industrial and commercial customers due to COVID-19 and higher self-generation by industrial customers, partially offset by increased usage by residential customers primarily due to COVID-19.
Economic Conditions
NIPSCO has a state-approved recovery mechanism that provides a means for full recovery of prudently incurred fuel costs. Fuel costs are treated as pass-through costs and have no impact on operating income recorded in the period. The fuel costs included in revenues are matched with the fuel cost expense recorded in the period and the difference is recorded on the Condensed Consolidated Balance Sheets (unaudited) as under-recovered or over-recovered fuel cost to be included in future customer billings.
COVID-19 has impacted many sectors of the economy. COVID-19 impacted Electric Operations in the second quarter of 2020, as described above. We continue to monitoring developments affecting our workforce, customers, suppliers and operations and will take additional measures as needed in an effort to help mitigate the impacts of the COVID-19 pandemic on our company and in our communities. See the COVID-19 discussion in the introduction to the "Executive Summary" for additional information.
Table of Contents
ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (continued)
NiSource Inc.
Electric Operations
Electric Supply
NIPSCO 2018 Integrated Resource Plan. Multiple factors, but primarily economic ones, including low natural gas prices, advancing cost effective renewable technology and increasing capital and operating costs associated with existing coal plants, have led NIPSCO to conclude in its October 2018 Integrated Resource Plan submission that NIPSCO’s current fleet of coal generation facilities will be retired earlier than previous Integrated Resource Plan’s had indicated.
The Integrated Resource Plan evaluated demand-side and supply-side resource alternatives to reliably and cost effectively meet NIPSCO customers' future energy requirements over the ensuing 20 years. The preferred option within the Integrated Resource Plan retires R.M. Schahfer Generating Station (Units 14, 15, 17, and 18) by 2023 and Michigan City Generating Station (Unit 12) by 2028. These units represent 2,080 MW of generating capacity, equal to 72% of NIPSCO’s remaining capacity and 100% of NIPSCO's remaining coal-fired generating capacity. In the second quarter of 2020, the MISO approved NIPSCO's plan to retire the R.M. Schahfer Generating Station units in 2023. The planned replacement in 2023 of approximately 1,400 MW of retiring coal-fired generation station could provide incremental capital investment opportunities of approximately $1.8 to $2.0 billion, primarily in 2022 and 2023. Refer to Note 8, "Property, Plant and Equipment" and Note 19-D, "Other Matters," in the Notes to Condensed Consolidated Financial Statements (unaudited) for further information.
The current replacement plan includes lower-cost, reliable, cleaner energy resources to be obtained through a combination of NIPSCO ownership and PPAs. Commercial negotiations are advancing on BTAs representing a significant amount of additional solar capacity. We also expect to secure additional agreements with counterparties and initiate regulatory compliance filings into 2021. Refer to Note 19-D, "Other Matters," in the Notes to Condensed Consolidated Financial Statements (unaudited) for additional information on the NIPSCO Integrated Resource Plan.
Table of Contents
ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (continued)
NiSource Inc.
Liquidity and Capital Resources
Greater Lawrence Incident: As discussed in the "Executive Summary" and Note 19, “Other Commitments and Contingencies,” in the Notes to the Condensed Consolidated Financial Statements (unaudited), we have recorded and paid costs associated with the Greater Lawrence Incident and have invested capital to replace the entire affected 45-mile cast iron and bare steel pipeline system that delivers gas to the impacted area. As discussed in the Executive Summary and Note 19 referenced earlier in this paragraph, we may incur additional expenses and liabilities in excess of our recorded liabilities and estimated additional costs associated with the Greater Lawrence Incident. Since the Greater Lawrence Incident and through June 30, 2020, we have collected $800 million from insurance providers; however, total costs related to the incident have exceeded the total amount of insurance coverage available under our policies. To date, this excess has primarily been funded through short-term borrowings. We plan to use the expected proceeds from the sale of the Massachusetts Business to pay down these short-term borrowings. For additional information, see Note 7, "Assets and Liabilities Held for Sale," in the Notes to the Condensed Consolidated Financial Statements (unaudited).
Operating Activities
Net cash from operating activities for the six months ended June 30, 2020 was $707.7 million, a decrease of $218.5 million compared to the six months ended June 30, 2019. This decrease was driven by year over year increase in net payments related to the Greater Lawrence Incident. During 2020, we paid approximately $162 million compared to insurance recoveries of $108 million, net of payments, during 2019. Offsetting these cash outflows are higher accounts receivable collections in 2020 compared to 2019.
Investing Activities
Net cash used for investing activities for the six months ended June 30, 2020 was $886.6 million, a decrease of $11.4 million compared to the six months ended June 30, 2019. This decrease was mostly attributable to lower capital expenditures partially offset by higher cost of removal expenditures in 2020.
Our capital expenditures for the six months ended June 30, 2020 were $819.3 million compared to $843.5 million for the comparable period in 2019. The decrease was driven by reduced spend related to the Greater Lawrence Pipeline Replacement and Electric TDSIC projects, partially offset by an increase in customer growth projects. We project total 2020 capital expenditures to be approximately $1.7 to $1.8 billion.
Our cost of removal expenditures for the six months ended June 30, 2020 were $66.7 million compared to $55.7 million for the comparable period in 2019. The increase was driven by additional cost of removal projects completed by NIPSCO and Columbia of Ohio.
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.
Long-term Debt. Refer to Note 17, “Long-Term Debt,” in the Notes to Condensed Consolidated Financial Statements (unaudited) for information on long-term debt activity.
Short-term Debt. Refer to Note 18, “Short-Term Borrowings,” in the Notes to Condensed Consolidated Financial Statements (unaudited) for information on short-term debt activity.
Net Available Liquidity. As of June 30, 2020, an aggregate of $1,982.0 million of net liquidity was available, including cash and credit available under the revolving credit facility and accounts receivable securitization programs.
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ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (continued)
NiSource Inc.
The following table displays our liquidity position as of June 30, 2020 and December 31, 2019:
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|
|
|
|
|
|
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(in millions)
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June 30, 2020
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December 31, 2019
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Current Liquidity
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|
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Revolving Credit Facility
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$
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1,850.0
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$
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1,850.0
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|
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Accounts Receivable Program(1)
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313.5
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353.2
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Less:
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|
|
|
|
|
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Commercial Paper
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—
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570.0
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|
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Accounts Receivable Program Utilized
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313.5
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353.2
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Letters of Credit Outstanding Under Credit Facility
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10.2
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10.2
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Add:
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Cash and Cash Equivalents
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142.2
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139.3
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Net Available Liquidity
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$
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1,982.0
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$
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1,409.1
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(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 and term loan agreement, which require us to maintain a debt to capitalization ratio that does not exceed 70%. A similar covenant in a 2005 private placement note purchase agreement requires us to maintain a debt to capitalization ratio that does not exceed 75%. As of June 30, 2020, the ratio was 63.8%.
Sale of Trade Accounts Receivables. Refer to Note 13, “Transfers of Financial Assets,” in the Notes to Condensed Consolidated Financial Statements (unaudited) for information on the sale of trade accounts receivable.
Credit Ratings. The credit rating agencies periodically review our ratings, taking into account factors such as our capital structure and earnings profile. The following table includes our and certain of our subsidiaries' credit ratings and ratings outlook as of June 30, 2020. In February 2020, S&P changed the outlook of us and certain of our subsidiaries from Negative to Stable. There were no other changes to the below credit ratings or outlooks since December 31, 2019.
A credit rating is not a recommendation to buy, sell, or hold securities, and may be subject to revision or withdrawal at any time by the assigning rating organization.
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S&P
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Moody's
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Fitch
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Rating
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Outlook
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Rating
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Outlook
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Rating
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Outlook
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NiSource
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BBB+
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Stable
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Baa2
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Stable
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BBB
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Stable
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NIPSCO
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BBB+
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Stable
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Baa1
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Stable
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BBB
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Stable
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Columbia of Massachusetts
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BBB+
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Stable
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Baa2
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Stable
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Not rated
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Not rated
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Commercial Paper
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A-2
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Stable
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P-2
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Stable
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F2
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Stable
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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, 2020, the collateral requirement that would be required in the event of a downgrade below the ratings trigger levels would amount to approximately $76.9 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, 2020, 382,917,033 shares of common stock and 440,000 shares of preferred stock were outstanding.
Contractual Obligations. Aside from the previously referenced issuances of long-term debt and payments associated with the Greater Lawrence Incident, there were no material changes during the six months ended June 30, 2020 to our contractual obligations as of December 31, 2019.
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ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (continued)
NiSource Inc.
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 19, “Other Commitments and Contingencies,” in the Notes to the Condensed Consolidated Financial Statements (unaudited) for information on guarantees.
Off Balance Sheet Arrangements
We, along with certain of our subsidiaries, enter into various agreements providing financial or performance assurance to third parties on behalf of certain subsidiaries. Such agreements include guarantees and stand-by letters of credit.
Refer to Note 19, “Other Commitments and Contingencies,” in the Notes to 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. Risk management for us is a multi-faceted process with oversight by the Risk Management Committee that requires constant communication, judgment and knowledge of specialized products and markets. Our senior management takes an active role in the risk management process and has developed policies and procedures that require specific administrative and business functions to assist in the identification, assessment and control of various risks. These may include, but are not limited to market, operational, financial, compliance and strategic risk types. In recognition of the increasingly varied and complex nature of the energy business, our risk management process, policies and procedures continue to evolve and are subject to ongoing review and modification.
Our Risk Management Committee has been actively engaged in monitoring the impact of COVID-19 on our business. See the COVID-19 discussion in the introduction to the "Executive Summary" for risks that have been identified related to COVID-19.
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 is reflected in our restricted cash balance, may fluctuate significantly during periods of high volatility in the energy commodity markets.
Refer to Note 11, "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, 2020 or December 31, 2019.
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 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 $3.4 million and $7.7 million for the three and six months ended June 30, 2020, and $5.1 million and $10.0 million for the three and six months ended June 30, 2019, 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 11, "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, 2020 and December 31, 2019.
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ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (continued)
NiSource Inc.
Credit Risk
Due to the nature of the industry, credit risk is embedded in many of our business activities. Our extension of credit is governed by a Corporate Credit Risk Policy. In addition, Risk Management Committee guidelines are in place which document management approval levels for credit limits, evaluation of creditworthiness, and credit risk mitigation efforts. Exposures to credit risks are monitored by the risk management function, which is independent of commercial operations. Credit risk arises due to the possibility that a customer, supplier or counterparty will not be able or willing to fulfill its obligations on a transaction on or before the settlement date. For derivative-related contracts, credit risk arises when counterparties are obligated to deliver or purchase defined commodity units of gas or power to us at a future date per execution of contractual terms and conditions. Exposure to credit risk is measured in terms of both current obligations and the market value of forward positions net of any posted collateral such as cash and letters of credit.
We closely monitor the financial status of our banking credit providers. We evaluate the financial status of our banking partners through the use of market-based metrics such as credit default swap pricing levels, and also through traditional credit ratings provided by major credit rating agencies.
Although individual state regulatory commissions have instituted regulatory moratoriums in connection with COVID-19 that impact our ability to pursue our credit risk mitigation practices for customer accounts receivable, we believe this to be temporary, and we expect to reinstate our common credit mitigation practices upon expiration of the state specific moratoriums. See the COVID-19 discussion in the introduction to the "Executive Summary" for risks that have been identified related to COVID-19.
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 related to COVID-19.
Refer to Note 14, "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, 2020.
Refer to Note 19, "Other Commitments and Contingencies," in the Notes to Condensed Consolidated Financial Statements (unaudited) for additional information about management judgment used in the development of estimates related to the Greater Lawrence Incident.
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.
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NiSource Inc.
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 fiscal quarter covered by this report that has materially affected, or is reasonably likely to materially affect, our internal control over financial reporting.