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 of January 1, 2024, we have changed our reportable segments from Gas Distribution Operations and Electric Operations to Columbia Operations and NIPSCO Operations. Our historical segment disclosures have been recast to be consistent with the current presentation. For additional information see Note 17, "Business Segment Information."
The Columbia Operations segment provides regulated natural gas service and transportation for residential, commercial and industrial customers in Ohio, Pennsylvania, Virginia, Kentucky, and Maryland. The NIPSCO Operations segment provides regulated gas and electric service in the northern part of Indiana for residential, commercial and industrial customers.
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 (unaudited):
17
ITEM 1. FINANCIAL STATEMENTS (continued)
NiSource Inc.
Notes to Condensed Consolidated Financial Statements (unaudited) (continued)
Three months ended September 30, 2024 (in millions) | Columbia Operations | NIPSCO Operations | Corporate and Other | Total | |||||||||||||||||||
| Gas Distribution | |||||||||||||||||||||||
| Residential | $ | $ | $ | $ | |||||||||||||||||||
| Commercial | |||||||||||||||||||||||
| Industrial | |||||||||||||||||||||||
| Off-system | |||||||||||||||||||||||
| Wholesale | |||||||||||||||||||||||
Miscellaneous(1) | |||||||||||||||||||||||
| Subtotal | $ | $ | $ | $ | |||||||||||||||||||
Electric Generation and Power Delivery | |||||||||||||||||||||||
| Residential | $ | — | $ | $ | — | $ | |||||||||||||||||
| Commercial | — | — | |||||||||||||||||||||
| Industrial | — | — | |||||||||||||||||||||
| Wholesale | — | — | |||||||||||||||||||||
| Public Authority | — | — | |||||||||||||||||||||
Miscellaneous(1) | — | — | |||||||||||||||||||||
| Subtotal | $ | — | $ | $ | — | $ | |||||||||||||||||
Total Customer Revenues(2) | |||||||||||||||||||||||
Other Revenues(3) | |||||||||||||||||||||||
| Total Operating Revenues | $ | $ | $ | $ | |||||||||||||||||||
(1)Amounts included in Columbia Operations are primarily related to earnings share mechanisms and late fees. Amounts included in NIPSCO Operations are primarily related to revenue refunds, public repairs and property rentals. (2)Customer revenue amounts exclude intersegment revenues. See Note 17, "Business Segment Information," for discussion of intersegment revenues. (3)Amounts included in Columbia Operations primarily relate to weather normalization adjustment mechanisms. Amounts included in NIPSCO Operations primarily relate to MISO multi-value projects and revenue from non-jurisdictional transmission assets. | |||||||||||||||||||||||
Three months ended September 30, 2023 (in millions) | Columbia Operations | NIPSCO Operations | Corporate and Other | Total | |||||||||||||||||||
| Gas Distribution | |||||||||||||||||||||||
| Residential | $ | $ | $ | $ | |||||||||||||||||||
| Commercial | |||||||||||||||||||||||
| Industrial | |||||||||||||||||||||||
| Off-system | |||||||||||||||||||||||
| Wholesale | |||||||||||||||||||||||
Miscellaneous(1) | |||||||||||||||||||||||
| Subtotal | $ | $ | $ | $ | |||||||||||||||||||
Electric Generation and Power Delivery | |||||||||||||||||||||||
| Residential | $ | — | $ | $ | — | $ | |||||||||||||||||
| Commercial | — | — | |||||||||||||||||||||
| Industrial | — | — | |||||||||||||||||||||
| Wholesale | — | — | |||||||||||||||||||||
| Public Authority | — | — | |||||||||||||||||||||
Miscellaneous(1) | — | — | |||||||||||||||||||||
| Subtotal | $ | — | $ | $ | — | $ | |||||||||||||||||
Total Customer Revenues(2) | |||||||||||||||||||||||
Other Revenues(3) | |||||||||||||||||||||||
| Total Operating Revenues | $ | $ | $ | $ | |||||||||||||||||||
(1)Amounts included in Columbia Operations are primarily related to earnings share mechanisms and late fees. Amounts included in NIPSCO Operations, are primarily related to revenue refunds, public repairs and property rentals. (2)Customer revenue amounts exclude intersegment revenues. See Note 17, "Business Segment Information," for discussion of intersegment revenues. (3)Amounts included in Columbia Operations are primarily relate to weather normalization adjustment mechanisms. Amounts included in NIPSCO Operations primarily relate to MISO multi-value projects and revenue from non-jurisdictional transmission assets. | |||||||||||||||||||||||
18
ITEM 1. FINANCIAL STATEMENTS (continued)
NiSource Inc.
Notes to Condensed Consolidated Financial Statements (unaudited) (continued)
Nine months ended September 30, 2024 (in millions) | Columbia Operations | NIPSCO Operations | Corporate and Other | Total | |||||||||||||||||||
| Gas Distribution | |||||||||||||||||||||||
| Residential | $ | $ | $ | $ | |||||||||||||||||||
| Commercial | |||||||||||||||||||||||
| Industrial | |||||||||||||||||||||||
| Off-system | |||||||||||||||||||||||
| Wholesale | |||||||||||||||||||||||
Miscellaneous(1) | |||||||||||||||||||||||
| Subtotal | $ | $ | $ | $ | |||||||||||||||||||
Electric Generation and Power Delivery | |||||||||||||||||||||||
| Residential | $ | — | $ | $ | — | $ | |||||||||||||||||
| Commercial | — | — | |||||||||||||||||||||
| Industrial | — | — | |||||||||||||||||||||
| Wholesale | — | — | |||||||||||||||||||||
| Public Authority | — | — | |||||||||||||||||||||
Miscellaneous(1) | — | — | |||||||||||||||||||||
| Subtotal | $ | — | $ | $ | — | $ | |||||||||||||||||
Total Customer Revenues(2) | |||||||||||||||||||||||
Other Revenues(3) | |||||||||||||||||||||||
| Total Operating Revenues | $ | $ | $ | $ | |||||||||||||||||||
(1)Amounts included in Columbia Operations are primarily related to earnings share mechanisms and late fees. Amounts included in NIPSCO Operations are primarily related to revenue refunds, public repairs and property rentals. (2)Customer revenue amounts exclude intersegment revenues. See Note 17, "Business Segment Information," for discussion of intersegment revenues. (3)Amounts included in Columbia Operations primarily relate to weather normalization adjustment mechanisms. Amounts included in NIPSCO Operations primarily relate to MISO multi-value projects and revenue from non-jurisdictional transmission assets. | |||||||||||||||||||||||
Nine months ended September 30, 2023 (in millions) | Columbia Operations | NIPSCO Operations | Corporate and Other | Total | |||||||||||||||||||
| Gas Distribution | |||||||||||||||||||||||
| Residential | $ | $ | $ | $ | |||||||||||||||||||
| Commercial | |||||||||||||||||||||||
| Industrial | |||||||||||||||||||||||
| Off-system | |||||||||||||||||||||||
| Wholesale | |||||||||||||||||||||||
Miscellaneous(1) | |||||||||||||||||||||||
| Subtotal | $ | $ | $ | $ | |||||||||||||||||||
Electric Generation and Power Delivery | |||||||||||||||||||||||
| Residential | $ | — | $ | $ | — | $ | |||||||||||||||||
| Commercial | — | — | |||||||||||||||||||||
| Industrial | — | — | |||||||||||||||||||||
| Wholesale | — | — | |||||||||||||||||||||
| Public Authority | — | — | |||||||||||||||||||||
Miscellaneous(1) | — | — | |||||||||||||||||||||
| Subtotal | $ | — | $ | $ | — | $ | |||||||||||||||||
Total Customer Revenues(2) | |||||||||||||||||||||||
Other Revenues(3) | |||||||||||||||||||||||
| Total Operating Revenues | $ | $ | $ | $ | |||||||||||||||||||
(1)Amounts included in Columbia Operations are primarily related to earnings share mechanisms and late fees. Amounts included in NIPSCO Operations, are primarily related to revenue refunds, public repairs and property rentals. (2)Customer revenue amounts exclude intersegment revenues. See Note 17, "Business Segment Information," for discussion of intersegment revenues. (3)Amounts included in Columbia Operations are primarily relate to weather normalization adjustment mechanisms. Amounts included in NIPSCO Operations primarily relate to MISO multi-value projects and revenue from non-jurisdictional transmission assets. | |||||||||||||||||||||||
19
ITEM 1. FINANCIAL STATEMENTS (continued)
NiSource Inc.
Notes to Condensed Consolidated Financial Statements (unaudited) (continued)
Customer Accounts Receivable. Accounts receivable on our Condensed Consolidated Balance Sheets (unaudited) includes both billed and unbilled amounts, as well as certain amounts that are not related to customer revenues. Unbilled amounts of accounts receivable relate to a portion of a customer’s consumption of gas or electricity from the date of the last cycle billing through the last day of the month (balance sheet date). Factors taken into consideration when estimating unbilled revenue include historical usage, customer rates, and weather. A significant portion of our operations are subject to seasonal fluctuations in sales. During the heating season, primarily from November through March, revenues and receivables from gas sales are more significant than in other months. The opening and closing balances of customer receivables for the nine months ended September 30, 2024 are presented in the table below. We had no significant contract assets or liabilities during the period. Additionally, we have not incurred any significant costs to obtain or fulfill contracts.
| (in millions) | Customer Accounts Receivable, Billed (less reserve) | Customer Accounts Receivable, Unbilled (less reserve) | |||||||||
| Balance as of December 31, 2023 | $ | $ | |||||||||
| Balance as of September 30, 2024 | |||||||||||
Utility revenues are billed to customers monthly on a cycle basis. We expect that substantially all customer accounts receivable will be collected following customer billing, as this revenue consists primarily of periodic, tariff-based billings for service and usage. We maintain common utility credit risk mitigation practices, including requiring deposits and actively pursuing collection of past due amounts. Our regulated operations also utilize certain regulatory mechanisms that facilitate recovery of bad debt costs within tariff-based rates, which provides further evidence of collectibility. It is probable that substantially all of the consideration to which we are entitled from customers will be collected upon satisfaction of performance obligations.
Allowance for Credit Losses. To evaluate for expected credit losses, customer account receivables are pooled based on similar risk characteristics, such as customer type, geography, payment terms, and related macro-economic risks. Expected credit losses are established using a model that considers historical collections experience, current information, and reasonable and supportable forecasts. Internal and external inputs are used in our credit model including, but not limited to, energy consumption trends, revenue projections, actual charge-offs data, recoveries data, shut-offs, customer delinquencies, final bill data, and inflation. We continuously evaluate available information relevant to assessing collectability of current and future receivables. We evaluate creditworthiness of specific customers periodically or following changes in facts and circumstances. When we become aware of a specific commercial or industrial customer's inability to pay, an allowance for expected credit losses is recorded for the relevant amount. We also monitor other circumstances that could affect our overall expected credit losses including, but not limited to, creditworthiness of overall population in service territories, adverse conditions impacting an industry sector, and current economic conditions.
20
ITEM 1. FINANCIAL STATEMENTS (continued)
NiSource Inc.
Notes to Condensed Consolidated Financial Statements (unaudited) (continued)
At each reporting period, we record expected credit losses to an allowance for credit losses account. When deemed to be uncollectible, customer accounts are written-off. A rollforward of our allowance for credit losses as of September 30, 2024 and December 31, 2023 are presented in the table below:
(in millions) | Columbia Operations | NIPSCO Operations | Corporate and Other | Total | |||||||||||||||||||
| Balance as of January 1, 2024 | $ | $ | $ | $ | |||||||||||||||||||
| Current period provisions | |||||||||||||||||||||||
| Write-offs charged against allowance | ( | ( | ( | ( | |||||||||||||||||||
| Recoveries of amounts previously written off | |||||||||||||||||||||||
| Balance as of September 30, 2024 | $ | $ | $ | $ | |||||||||||||||||||
(in millions) | Columbia Operations | NIPSCO Operations | Corporate and Other | Total | |||||||||||||||||||
| Balance as of January 1, 2023 | $ | $ | $ | $ | |||||||||||||||||||
| Current period provisions | |||||||||||||||||||||||
| Write-offs charged against allowance | ( | ( | ( | ||||||||||||||||||||
| Recoveries of amounts previously written off | |||||||||||||||||||||||
| Balance as of December 31, 2023 | $ | $ | $ | $ | |||||||||||||||||||
4. Noncontrolling Interests
Variable Interest Entities. A VIE is an entity in which the controlling interest is determined through means other than a majority voting interest. NIPSCO is a member of JVs that own and operate two wind facilities, Rosewater and Indiana Crossroads Wind, which have 102 MW and 302 MW of nameplate capacity, respectively. NIPSCO is also a member of JVs that own two solar facilities, Indiana Crossroads Solar and Dunns Bridge I, which have a nameplate capacity of 200 MW and 265 MW, respectively. We have determined that these JVs are VIEs. NIPSCO controls the decisions that are significant to these entities' ongoing operations and economic results. Therefore, we have concluded that NIPSCO is the primary beneficiary and have consolidated all four entities.
Members of each respective JV include NIPSCO (who is the managing member) and a tax equity partner. Earnings, tax attributes and cash flows are allocated to both NIPSCO and the tax equity partner in varying percentages by category and over the life of the partnership. NIPSCO and each tax equity partner contributed cash to the respective JV. Once the tax equity partner has earned their negotiated rate of return and the JV has reached a stated contractual date, NIPSCO has the option to purchase the remaining interest in the respective JV from the tax equity partner. NIPSCO has an obligation to purchase 100 % of the electricity generated by each commercially operational JV.
We did not provide any financial or other support during the quarter that was not previously contractually required.
21
ITEM 1. FINANCIAL STATEMENTS (continued)
NiSource Inc.
Notes to Condensed Consolidated Financial Statements (unaudited) (continued)
Our Condensed Consolidated Balance Sheets (unaudited) included the following assets and liabilities associated with VIEs.
| (in millions) | September 30, 2024 | December 31, 2023 | |||||||||
| Net Property, Plant and Equipment | $ | $ | |||||||||
| Current assets | |||||||||||
Total assets(1) | |||||||||||
| Current liabilities | |||||||||||
| Asset retirement obligations | |||||||||||
Total liabilities(1)(2) | $ | $ | |||||||||
(1)The assets of each consolidated VIE can only be used to settle obligations of the respective consolidated VIE. The creditors of the liabilities of the VIEs do not have recourse to the general credit of the primary beneficiary.
(2)In addition to the amounts disclosed above there is a de minimis amount of other noncurrent assets and liabilities at Rosewater as of September 30, 2024.
(2)In addition to the amounts disclosed above there is a de minimis amount of other noncurrent assets and liabilities at Rosewater as of September 30, 2024.
5. Earnings Per Share
The calculations of basic and diluted EPS are based on the weighted average number of shares of common stock and potential common stock outstanding during the period. Diluted EPS includes the incremental effects of the various long-term incentive compensation plans and ATM forward sale agreements under the treasury stock method when the impact would be dilutive (See Note 6, "Equity,"). For the purposes of determining diluted EPS, for the three and nine months ended September 30, 2023, the shares underlying the purchase contracts included within the Equity Units were included in the calculation of potential common stock outstanding using the if-converted method under US GAAP and we assumed share settlement of the remaining purchase contract payment balance from our Equity Units based on the average share price during the period. A numerator adjustment was reflected in the calculation of diluted EPS for interest expense incurred in the three and nine months ended September 30, 2023, net of tax, related to the purchase contracts. The purchase contracts were settled on December 1, 2023.
We began using the two-class method of computing earnings per share in 2023 because we have participating securities in the form of non-vested restricted stock units with a non-forfeitable right to dividend equivalents, for which vesting is predicated solely on the passage of time. The calculation of earnings per share using the two-class method excludes income attributable to these participating securities from the numerator and excludes the dilutive impact of those shares from the denominator.
22
ITEM 1. FINANCIAL STATEMENTS (continued)
NiSource Inc.
Notes to Condensed Consolidated Financial Statements (unaudited) (continued)
The following table presents the calculation of our basic and diluted EPS:
| Three Months Ended September 30, | Nine Months Ended September 30, | ||||||||||||||||||||||
| (in millions, except per share amounts) | 2024 | 2023 | 2024 | 2023 | |||||||||||||||||||
| Numerator: | |||||||||||||||||||||||
Net Income Available to Common Shareholders | $ | $ | $ | $ | |||||||||||||||||||
| Less: Income allocated to participating securities | |||||||||||||||||||||||
Net Income Available to Common Shareholders - Basic | |||||||||||||||||||||||
| Add: Dilutive effect of Equity Units | |||||||||||||||||||||||
Net Income Available to Common Shareholders - Diluted | $ | $ | $ | $ | |||||||||||||||||||
| Denominator: | |||||||||||||||||||||||
| Average common shares outstanding - Basic | |||||||||||||||||||||||
| Dilutive potential common shares: | |||||||||||||||||||||||
| Equity Units purchase contracts | |||||||||||||||||||||||
| Equity Units purchase contract payment balance | |||||||||||||||||||||||
| Shares contingently issuable under employee stock plans | |||||||||||||||||||||||
| Shares restricted under employee stock plans | |||||||||||||||||||||||
ATM forward sale agreements | |||||||||||||||||||||||
| Average Common Shares - Diluted | |||||||||||||||||||||||
| Earnings per common share: | |||||||||||||||||||||||
| Basic | $ | $ | |||||||||||||||||||||
| Diluted | $ | $ | |||||||||||||||||||||
6. Equity
ATM Program. In February 2024, we entered into eight separate equity distribution agreements pursuant to which we are able to sell up to an aggregate of $900.0 million of our common stock.
In February 2024, under the ATM program, we executed a forward sale agreement, which allowed us to issue a fixed number of shares at a price to be settled in the future. The forward purchaser under our forward sale agreement borrowed 7,757,951 shares from third parties, which the forward purchaser sold, through its affiliated agent, at a weighted average price of $25.78 per share. On September 17, 2024 we settled all the shares under the forward sale agreement for $199.9 million, based on a net price of $25.77 per share.
In May 2024, under the ATM program, we executed a forward sale agreement, which allowed us to issue a fixed number of shares at a price to be settled in the future. The forward purchaser under our forward sale agreement borrowed 10,390,000 shares from third parties, which the forward purchaser sold, through its affiliated agent, at a weighted average price of $28.87 per share. On September 11, 2024 we settled all the shares under the forward sale agreement for $299.1 million, based on a net price of $28.79 per share.
In September 2024, under the ATM program, we executed a forward sale agreement, which allows us to issue a fixed number of shares at a price to be settled in the future. The forward purchaser under our forward sale agreement borrowed 1,495,949 shares from third parties, which the forward purchaser sold, through its affiliated agent, at a weighted average price of $34.01 per share. We may settle the forward sale agreement in shares, cash or net shares, by October 30, 2025. Had we settled all the shares under the forward sale agreement at September 30, 2024, we would have received approximately $50.4 million, based on a net price of $33.72 per share.
23
ITEM 1. FINANCIAL STATEMENTS (continued)
NiSource Inc.
Notes to Condensed Consolidated Financial Statements (unaudited) (continued)
In September 2024, under the ATM program, we executed a second forward sale agreement, which allows us to issue a fixed number of shares at a price to be settled in the future. The forward purchasers under our forward sale agreement borrowed 1,500,000 shares from third parties, which the forward purchaser sold, through its affiliated agent, at a weighted average price of $34.32 per share. We may settle the forward sale agreement in shares, cash or net shares between October 1, 2024, and October 30, 2025. Had we settled all the shares under the forward sale agreement at October 1, 2024, we would have received approximately $51.1 million, based on a net price of $34.06 per share.
As of September 30, 2024, the ATM program (inclusive of open forward sale agreements) had approximately $297.7 million of equity available for issuance. The program expires on December 31, 2025.
Series A Preferred Stock. There were no dividends declared per share for the Series A Preferred Stock during the three months ended September 30, 2024 and 2023. Dividends declared per share for the Series A Preferred Stock were zero and $28.25 during the nine months ended September 30, 2024 and 2023, respectively.
On June 15, 2023, we redeemed all 400,000 outstanding shares of Series A Preferred Stock for a redemption price of $1,000 per share or $400.0 million in total.
Series B and B-1 Preferred Stock. Dividends declared per share for the Series B Preferred Stock were zero and $406.25 during the three months ended September 30, 2024 and 2023, respectively. Dividends declared per share for the Series B Preferred Stock were $406.25 and $1,625.0 during the nine months ended September 30, 2024 and 2023, respectively.
On March 15, 2024, we redeemed all 20,000 outstanding shares of Series B Preferred Stock for a redemption price of $25,000 per share and all 20,000 outstanding shares of Series B-1 Preferred Stock for a redemption price of $0.01 per share or $500.0 million in total. Following the redemption, dividends ceased to accrue on the shares of Series B Preferred Stock, shares of the Series B Preferred Stock and Series B-1 Preferred Stock were no longer deemed outstanding and all rights of the holders of such shares of Series B Preferred Stock and Series B-1 Preferred Stock terminated. In conjunction with the redemption, we recorded a $14.0 million preferred stock redemption premium, calculated as the difference between the carrying value on the redemption date of the Series B Preferred Stock and Series B-1 Preferred Stock and the total amount of consideration paid to redeem, which was recorded as a reduction to retained earnings during the first quarter of 2024. We have not recognized an excise tax liability under the IRA in connection with this redemption as we issued common stock in 2024 in excess of the fair value of the Series B Preferred Stock and Series B-1 Preferred Stock redeemed.
In March 2024, we filed a Certificate of Elimination to our Amended and Restated Certificate of Incorporation with the Secretary of State of Delaware to eliminate from the Amended and Restated Certificate of Incorporation all matters set forth in the Certificate of Designations with respect to the Series B Preferred Stock and the Certificate of Designations with respect to the Series B-1 Preferred Stock. As a result, the 20,000 shares that were previously designated as Series B Preferred Stock and the 20,000 shares that were previously designated as Series B-1 Preferred Stock were returned to the status of authorized but unissued shares of preferred stock, par value $0.01 per share, without designation as to series. The Certificate of Elimination does not change the total number of authorized shares of capital stock of NiSource or the total number of authorized shares of preferred stock. We voluntarily delisted the preferred stock from the New York Stock Exchange.
Equity Units. On December 1, 2023, we issued 33,898,837 shares of our common stock under the purchase contract component of the Corporate Units. As of December 1, 2023, each holder of Corporate Units was deemed to have automatically delivered to us the related Series C Mandatory Convertible Preferred Stock that were components of the Corporate Units in full satisfaction of such holder’s obligations under the related purchase contract, and all 862,500 shares of Series C Mandatory Convertible Preferred Stock were returned to the status of authorized but unissued preferred stock, par value of $0.01 per share, without designation as to series. We voluntarily delisted the Corporate Units from the New York Stock Exchange.
24
ITEM 1. FINANCIAL STATEMENTS (continued)
NiSource Inc.
Notes to Condensed Consolidated Financial Statements (unaudited) (continued)
7. Short-Term Borrowings
We generate short-term borrowings from our revolving credit facility, commercial paper program, accounts receivable transfer programs, and term credit agreements. Each of these borrowing sources is described further below.
Revolving Credit Facility. We maintain a revolving credit facility to fund ongoing working capital requirements, including the provision of liquidity support for our commercial paper program, provide for issuance of letters of credit and also for general corporate purposes. Our revolving credit facility has a program limit of $1.85 billion and is comprised of a syndicate of banks. We had no
Commercial Paper Program. On February 9, 2024 we increased our commercial paper program limit from $1.50 billion to $1.85 billion. We had $257.0 million and $1,061.0 million of commercial paper outstanding with weighted-average interest rates of 4.95 % and 5.65 % as of September 30, 2024 and December 31, 2023, respectively.
Accounts Receivable Transfer Programs. 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 consolidated special purpose entities. The three agreements expire between May 2025 and October 2025 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 September 30, 2024, the maximum amount of debt that could be borrowed related to our accounts receivable programs was $225.0 million.
We had zero and $337.6 million of short-term borrowings related to the securitization transactions as of September 30, 2024 and December 31, 2023, respectively.
For the nine months ended September 30, 2024 and 2023, $337.6 million and $62.2 million, respectively were recorded as cash flows used for financing activities related to the change in short-term borrowings due to securitization transactions. For the accounts receivable transfer programs, we pay used facility fees for amounts borrowed, unused commitment fees for amounts not borrowed, and upfront renewal fees. Fees associated with the securitization transactions were $0.4 million and $0.5 million for the three months ended September 30, 2024 and 2023, and $1.3 million and $2.1 million for the nine months ended September 30, 2024 and 2023, 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.
Term Credit Agreements. At December 31, 2023, we had $1.0 650.0 million outstanding under term credit agreements with interest rates of 6.41 % and 6.50 %, respectively. On January 3, 2024, we terminated and repaid in full our $1.0 billion term credit agreement and our $650.0 million term credit agreement with proceeds from the NIPSCO Minority Interest Transaction.
Items listed above, excluding the term credit agreements, are presented net in the Condensed Statements of Consolidated Cash Flows (unaudited) as their maturities are less than 90 days.
8. Long-Term Debt
On March 14, 2024, we completed the issuance and sale of $650.0 million of 5.350 % senior unsecured notes maturing in 2034, which resulted in approximately $642.6 million of net proceeds after discount and debt issuance costs.
On May 16, 2024, we completed the issuance and sale of $500.0 million of 6.950 % fixed-to-fixed reset rate junior subordinated notes maturing in 2054, which resulted in approximately $493.4 million of net proceeds after debt issuance costs. The subordinated notes bear interest (i) from and including May 16, 2024 to, but excluding, November 30, 2029 at a rate of 6.950 % per annum and (ii) from and including November 30, 2029, during each five-year reset period at a rate per annum equal to the five-year U.S. treasury rate (determined as described in the prospectus supplement dated May 13, 2024, which was filed with the SEC on May 14, 2024) as of the then most recent reset interest determination date plus a spread of 2.451 %, to be reset on each reset date. At our option, we may redeem some or all of the subordinated notes during specified periods, and upon the occurrence of certain ratings or tax events, all as described in the prospectus supplement. In accordance with terms of the subordinated notes, we have the right, from time to time, to defer the payment of interest on the outstanding subordinated notes
25
ITEM 1. FINANCIAL STATEMENTS (continued)
NiSource Inc.
Notes to Condensed Consolidated Financial Statements (unaudited) (continued)
on one or more occasions for up to ten consecutive years. In the event that we were to exercise such right to defer interest on the subordinated notes, we would not be able to pay cash dividends on the common stock during the periods in which such payments were deferred. The subordinated notes were issued pursuant to a Subordinated Indenture, dated as of May 16, 2024, between us and The Bank of New York Mellon, as trustee, as supplemented by the First Supplemental Indenture thereto, dated as of May 16, 2024.
On September 9, 2024, we completed the issuance and sale of $500.0 million of 6.375 % fixed-to-fixed reset rate junior subordinated notes maturing in 2055, which resulted in approximately $493.6 million of net proceeds after debt issuance costs. The subordinated notes bear interest (i) from and including September 9, 2024 to, but excluding, March 31, 2035 at a rate of 6.375 % per annum and (ii) from and including March 31, 2035, during each five-year reset period at a rate per annum equal to the five-year U.S. treasury rate (determined as described in the prospectus supplement dated September 3, 2024, which was filed with the SEC on September 4, 2024) as of the then most recent reset interest determination date plus a spread of 2.527 %, to be reset on each reset date. At our option, we may redeem some or all of the subordinated notes during specified periods, and upon the occurrence of certain ratings or tax events, all as described in the prospectus supplement. In accordance with terms of the subordinated notes, we have the right, from time to time, to defer the payment of interest on the outstanding subordinated notes on one or more occasions for up to ten consecutive years. In the event that we were to exercise such right to defer interest on the subordinated notes, we would not be able to pay cash dividends on the common stock during the periods in which such payments were deferred. The subordinated notes were issued pursuant to a Subordinated Indenture, dated as of May 16, 2024, between us and The Bank of New York Mellon, as trustee, as supplemented by the Second Supplemental Indenture thereto, dated as of September 9, 2024.
9. Asset Retirement Obligations
26
ITEM 1. FINANCIAL STATEMENTS (continued)
NiSource Inc.
Notes to Condensed Consolidated Financial Statements (unaudited) (continued)
10. Regulatory Matters
Renewable generation filings
In March 2024, NIPSCO filed a petition with the IURC to issue an order modifying its November 22, 2023 order to approve direct ownership of the Gibson project. Also, in March 2024, NIPSCO filed a petition with the IURC to issue an order modifying its June 29, 2021 order to approve direct ownership of the Fairbanks project. Hearings for both the Gibson project and Fairbanks project were held in June 2024 and July 2024, respectively, with orders approving direct ownership of both projects received in August 2024.
WAM system filing
In March 2024, NIPSCO filed a petition with the IURC for authority to defer, as a regulatory asset, certain costs, including depreciation and amortization incurred in connection with improvements to its information technology systems through the design, development, and implementation of a new WAM program for the scheduling, dispatch, and execution of work and the management of underlying assets. These improvements are part of our enterprise-wide transformation roadmap which seeks to optimize our field work and reduce enterprise risk. The petition also included the confirmation that the WAM program assets, including the requested regulatory assets, will be included in NIPSCO's rate base for ratemaking purposes in rate cases after the WAM assets have been placed in service. The hearing was held in August 2024, and a final order approving NIPSCO's request was issued in September 2024 and NIPSCO recorded a deferral resulting in a regulatory asset of $16.9 million.
NIPSCO Gas Peaker filing
In September 2023, NIPSCO filed a request for issuance of a certificate of public convenience and necessity for an approximately 400 MW natural gas peaking generation facility with the IURC, which was supplemented in January 2024 based on updates on availability of certain key equipment. A final order was received in October 2024 approving the request.
Columbia of Virginia CARE Plan
On May 22, 2024, Columbia Gas of Virginia filed an application for approval to amend and extend its Conservation and Ratemaking Efficiency ("CARE") Plan. In September 2024, the Virginia State Corporation Commission issued its final order determining that the CARE Plan meets the requirements and approved the plan with all proposed measures effective January 1, 2025 through December 31, 2027.
Regulatory deferral related to renewable energy investments
In accordance with the accounting principles of ASC 980, we recognize a regulatory liability or asset for amounts representing the timing difference between the profit earned from the JVs and the amount included in regulated rates to recover our approved investments in consolidated JVs. The amounts recorded in income will ultimately reflect the amount allowed in regulated rates to recover our investments over the useful life of the projects. The offset to the regulatory liability or asset associated with our renewable investments included in regulated rates is recorded in "Depreciation and amortization" on the Condensed Statements of Consolidated Income (unaudited). NiSource recorded depreciation expense of $24.2 million and $40.8 million for the three and nine months ended September 30, 2024, and a decrease to depreciation expense of $19.0 million and $9.7 million for the three and nine months ended September 30, 2023, respectively. Following the implementation of the NIPSCO electric base rate case implemented in August 2023, we began recognizing amounts to recover our investments of projects that have been placed in service. Refer to Note 4, "Noncontrolling Interests," for additional information.
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.
Derivatives Not Designated as Hedging Instruments
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 on behalf of our customers, associated with natural gas purchases or sales by economically hedging the various gas cost components using a combination of
27
ITEM 1. FINANCIAL STATEMENTS (continued)
NiSource Inc.
Notes to Condensed Consolidated Financial Statements (unaudited) (continued)
futures, options, forwards or other derivative contracts. At September 30, 2024 and December 31, 2023, we had 64.4 MMDth and 76.1 MMDth, respectively, of net energy derivative volumes outstanding related to our natural gas hedges.
NIPSCO has received IURC approval to lock in a fixed price for its natural gas customers using long-term forward purchase instruments and is limited to 20 % of NIPSCO's average annual GCA purchase volume. As of September 30, 2024, the remaining terms of these instruments range from to three years . Likewise, Columbia of Pennsylvania has received approval for a 24-month rolling hedge program. The hedging program was executed in December 2023, with an effective date of April 1, 2024 and will continue in perpetuity. The program is designed to financially hedge approximately 20% of the customer’s annual demand. All unrealized gains and losses on these derivative contracts are deferred as regulatory liabilities or assets and all realized gains and losses are remitted to or collected from customers through the relevant cost recovery mechanism.
Risk management assets and liabilities on our derivatives are presented on the Condensed Consolidated Balance Sheets (unaudited) as shown below:
| September 30, 2024 | December 31, 2023 | ||||||||||||||||||||||
| (in millions) | Assets | Liabilities | Assets | Liabilities | |||||||||||||||||||
Current(1) | |||||||||||||||||||||||
| Derivatives not designated as hedging instruments | $ | $ | $ | $ | |||||||||||||||||||
| Total | $ | $ | $ | $ | |||||||||||||||||||
Noncurrent(2) | |||||||||||||||||||||||
| Derivatives not designated as hedging instruments | $ | $ | $ | $ | |||||||||||||||||||
| Total | $ | $ | $ | $ | |||||||||||||||||||
(1)Current assets and liabilities are presented in "Prepayments and other" and "Other accruals", respectively, on the Condensed Consolidated Balance Sheets (unaudited).
(2)Noncurrent assets and liabilities are presented in "Deferred charges and other" and "Other noncurrent liabilities and deferred credits", respectively, on the Condensed Consolidated Balance Sheets (unaudited).
Our commodity price risk management derivative instruments are subject to enforceable master netting arrangements or similar agreements. No collateral was either received or posted related to our outstanding derivative positions at September 30, 2024. If the above gross asset and liability positions were presented net of amounts owed or receivable from counterparties, we would report a net asset position of $12.2 million and $13.9 million at September 30, 2024 and December 31, 2023, respectively.
The following table summarizes the gains and losses associated with the commodity price risk programs deferred as regulatory assets and liabilities:
| (in millions) | September 30, 2024 | December 31, 2023 | |||||||||
| Regulatory Assets | |||||||||||
| Losses on commodity price risk programs | $ | $ | |||||||||
| Regulatory Liabilities | |||||||||||
| Gains on commodity price risk programs | |||||||||||
Derivatives Designated as Hedging Instruments
Interest rate risk management. As of September 30, 2024 and December 31, 2023 we had no active interest rate swap positions. The overall net loss related to settled interest rate swaps is recorded in AOCI. We amortize the net loss over the life of the debt associated with these swaps as we recognize interest expense. These amounts are immaterial for the three and nine months ended September 30, 2024 and 2023 and are recorded in "Interest expense, net" on the Condensed Statements of Consolidated Income (unaudited). Amounts expected to be reclassified to earnings during the next twelve months are immaterial. See Note 16, "Accumulated Other Comprehensive Loss," for additional information.
Interest rate risk management. As of September 30, 2024 and December 31, 2023 we had no active interest rate swap positions. The overall net loss related to settled interest rate swaps is recorded in AOCI. We amortize the net loss over the life of the debt associated with these swaps as we recognize interest expense. These amounts are immaterial for the three and nine months ended September 30, 2024 and 2023 and are recorded in "Interest expense, net" on the Condensed Statements of Consolidated Income (unaudited). Amounts expected to be reclassified to earnings during the next twelve months are immaterial. See Note 16, "Accumulated Other Comprehensive Loss," for additional information.
28
ITEM 1. FINANCIAL STATEMENTS (continued)
NiSource Inc.
Notes to Condensed Consolidated Financial Statements (unaudited) (continued)
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 September 30, 2024 and December 31, 2023:
Recurring Fair Value Measurements September 30, 2024 (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 September 30, 2024 | |||||||||||||||||||
| Assets | |||||||||||||||||||||||
| Risk management assets | $ | $ | $ | $ | |||||||||||||||||||
| Available-for-sale debt securities | |||||||||||||||||||||||
| Total | $ | $ | $ | $ | |||||||||||||||||||
| Liabilities | |||||||||||||||||||||||
| Risk management liabilities | $ | $ | $ | $ | |||||||||||||||||||
| Total | $ | $ | $ | $ | |||||||||||||||||||
Recurring Fair Value Measurements December 31, 2023 (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, 2023 | |||||||||||||||||||
| Assets | |||||||||||||||||||||||
| Risk management assets | $ | $ | $ | $ | |||||||||||||||||||
| Available-for-sale debt securities | |||||||||||||||||||||||
| Total | $ | $ | $ | $ | |||||||||||||||||||
| Liabilities | |||||||||||||||||||||||
| Risk management liabilities | $ | $ | $ | $ | |||||||||||||||||||
| Total | $ | $ | $ | $ | |||||||||||||||||||
Risk Management Assets and Liabilities. Risk management assets and liabilities include exchange-traded NYMEX futures and NYMEX options and non-exchange-based forward purchase contracts.
Level 1- When utilized, exchange-traded derivative contracts are based on unadjusted quoted prices in active markets and are classified within Level 1. These financial assets and liabilities are secured with cash on deposit with the exchange; therefore, nonperformance risk has not been incorporated into these valuations. These financial assets and liabilities are deemed to be cleared and settled daily by NYMEX as the related cash collateral is posted with the exchange. As a result of this exchange rule, NYMEX derivatives are considered to have no fair value at the balance sheet date for financial reporting purposes, and are presented in Level 1 net of posted cash; however, the derivatives remain outstanding and are subject to future commodity price fluctuations until they are settled in accordance with their contractual terms.
Level 2- Certain non-exchange-traded derivatives are valued using broker or over-the-counter, on-line exchanges. In such cases, these non-exchange-traded derivatives are classified within Level 2. Non-exchange-based derivative instruments include swaps, forwards, and options. In certain instances, these instruments may utilize models to measure fair value. We use a similar model to value similar instruments. Valuation models utilize various inputs that include quoted prices for similar assets or liabilities in active markets, quoted prices for identical or similar assets or liabilities in markets that are not active, other observable inputs for the asset or liability and market-corroborated inputs, (i.e., inputs derived principally from or corroborated by observable market data by correlation or other means). Where observable inputs are available for substantially the full term of the asset or liability, the instrument is categorized within Level 2.
29
ITEM 1. FINANCIAL STATEMENTS (continued)
NiSource Inc.
Notes to Condensed Consolidated Financial Statements (unaudited) (continued)
Level 3- Certain derivatives trade in less active markets with a lower availability of pricing information and models may be utilized in the valuation. When such inputs have a significant impact on the measurement of fair value, the instrument is categorized within Level 3.
Credit risk is considered in the fair value calculation of derivative instruments that are not exchange-traded. Credit exposures are adjusted to reflect collateral agreements that reduce exposures. As of September 30, 2024 and December 31, 2023, there were no
NIPSCO and Columbia of Pennsylvania have entered into long-term forward natural gas purchase instruments to lock in a fixed price for 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.
Our available-for-sale debt securities impairments are recognized periodically using an allowance approach. 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 the security's fair value is less than its amortized cost basis. If certain amounts recorded 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. As of September 30, 2024 and December 31, 2023, we have $0.2 million and $0.6 million, respectively, recorded 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.
30
The amortized cost, gross unrealized gains and losses, allowance for credit losses, and fair value of available-for-sale securities at September 30, 2024 and December 31, 2023 were:
September 30, 2024 (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 | $ | $ | $ | ( | $ | $ | |||||||||||||||||||||||
| Corporate/Other debt securities | ( | ( | |||||||||||||||||||||||||||
| Total | $ | $ | $ | ( | $ | ( | $ | ||||||||||||||||||||||
December 31, 2023 (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 | $ | $ | $ | ( | $ | $ | |||||||||||||||||||||||
| Corporate/Other debt securities | ( | ( | |||||||||||||||||||||||||||
| Total | $ | $ | $ | ( | $ | ( | $ | ||||||||||||||||||||||
(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 $41.2 million and $66.5 million, respectively, at September 30, 2024.
(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 $58.7 million and $74.8 million, respectively, at December 31, 2023.
Net realized gains and losses on available-for-sale securities were $0.1 million and $0.5 million for the three and nine months ended September 30, 2024, and zero and $0.6 million for the three and nine months ended September 30, 2023.
The cost of maturities sold is based upon specific identification. At September 30, 2024 there were no U.S. Treasury debt securities or Corporate/Other debt securities with maturities of less than a year. At December 31, 2023, approximately $16.8 million of U.S. Treasury debt securities and approximately $4.9 million of Corporate/Other debt securities had maturities of less than a year.
Non-recurring Fair Value Measurements
We measure the fair value of certain assets, primarily goodwill, on a non-recurring basis, typically when events or changes in circumstances indicate that the carrying amount of the assets may not be recoverable.
B. Other Fair Value Disclosures for Financial Instruments. The carrying amount of cash and cash equivalents, restricted cash, notes receivable, customer deposits and short-term borrowings is a reasonable estimate of fair value due to their liquid or short-term nature. Our long-term borrowings are recorded at historical amounts.
The following method and assumptions were used to estimate the fair value of each class of financial instruments.
Long-term Debt. The fair value of outstanding long-term debt is estimated based on the quoted market prices for the same or similar securities. Certain premium costs associated with the early settlement of long-term debt are not taken into consideration in determining fair value. These fair value measurements are classified within Level 2 of the fair value hierarchy. As of September 30, 2024, there was no change in the method or significant assumptions used to estimate the fair value of long-term debt.
The carrying amount and estimated fair values of these financial instruments were as follows:
| (in millions) | Carrying Amount as of September 30, 2024 | Estimated Fair Value as of September 30, 2024 | Carrying Amount as of Dec. 31, 2023 | Estimated Fair Value as of Dec. 31, 2023 | |||||||||||||||||||
| Long-term debt (including current portion) | $ | $ | $ | $ | |||||||||||||||||||
31
ITEM 1. FINANCIAL STATEMENTS (continued)
NiSource Inc.
Notes to Condensed Consolidated Financial Statements (unaudited) (continued)
13. Income Taxes
Our interim effective tax rates reflect the estimated annual effective tax rates for 2024 and 2023 applied to year-to-date pretax income, adjusted for tax expense associated with certain discrete items. The effective tax rates for the three months ended September 30, 2024 and 2023 were 14.1 % and 3.7 %, respectively. The effective tax rates for the nine months ended September 30, 2024 and 2023 were 15.4 17.7 %, respectively. These effective tax rates differ from the federal statutory tax rate of 21 % primarily due to renewable partnership income, amortization of excess deferred federal income tax liabilities, as specified in the TCJA, tax credits, state flow through, and other permanent book-to-tax differences.
The increase in the three-month effective tax rate of 10.4 % in 2024 compared to 2023 was driven by higher renewable partnership income in 2023 resulting from HLBV allocation of earnings due to solar projects going into service, offset by higher non-taxable AFUDC equity recorded on higher construction work in process balances in the current quarter.
As of September 30, 2024, there have been no material changes to our unrecognized tax benefits or possible changes that could reasonably be expected to occur during the next twelve months. See Note 15 to the Company’s Consolidated Financial Statements in the Annual Report on Form 10-K for the year ended December 31, 2023, for a discussion of these unrecognized tax benefits.
14. Pension and Other Postemployment 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 such employees may become eligible for these benefits if they reach retirement age while working for us. The expected cost of such benefits is accrued during the employees' years of service. We determined that, for certain rate-regulated subsidiaries, the future recovery of postretirement benefit costs is probable, and we record regulatory assets and liabilities for amounts that would otherwise have been recorded to expense or accumulated other comprehensive loss. Current rates of rate-regulated companies include postretirement benefit costs, including amortization of the regulatory assets and liabilities that arose prior to inclusion of these costs in rates. For most plans, cash contributions are remitted to grantor trusts.
For the nine months ended September 30, 2024 and 2023, we contributed $1.9 million and $2.6 million, respectively to our pension plans and $18.3 million and $16.7 million, respectively to our OPEB plans.
32
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 nine months ended September 30, 2024 and 2023:
| Pension Benefits | OPEB | ||||||||||||||||||||||
Three Months Ended September 30, (in millions) | 2024 | 2023 | 2024 | 2023 | |||||||||||||||||||
Components of Net Periodic Benefit Cost(1) | |||||||||||||||||||||||
| Service cost | $ | $ | $ | $ | |||||||||||||||||||
| Interest cost | |||||||||||||||||||||||
| Expected return on assets | ( | ( | ( | ( | |||||||||||||||||||
| Amortization of prior service credit | ( | ( | |||||||||||||||||||||
| Recognized actuarial loss | |||||||||||||||||||||||
| Settlement loss | |||||||||||||||||||||||
| Total Net Periodic Benefit Cost | $ | $ | $ | $ | |||||||||||||||||||
(1)The service cost component and all non-service cost components of net periodic benefit (income) cost are presented in "Operation and maintenance" and "Other, net," respectively, on the Condensed Statements of Consolidated Income (unaudited). | |||||||||||||||||||||||
| Pension Benefits | OPEB | ||||||||||||||||||||||
Nine Months Ended September 30, (in millions) | 2024 | 2023 | 2024 | 2023 | |||||||||||||||||||
Components of Net Periodic Benefit Cost(1) | |||||||||||||||||||||||
| Service cost | $ | $ | $ | $ | |||||||||||||||||||
| Interest cost | |||||||||||||||||||||||
| Expected return on assets | ( | ( | ( | ( | |||||||||||||||||||
| Amortization of prior service credit | ( | ( | |||||||||||||||||||||
| Recognized actuarial loss | |||||||||||||||||||||||
| Settlement loss | |||||||||||||||||||||||
| Total Net Periodic Benefit Cost | $ | $ | $ | $ | |||||||||||||||||||
(1)The service cost component and all non-service cost components of net periodic benefit (income) cost are presented in "Operation and maintenance" and "Other, net," respectively, on the Condensed Statements of Consolidated Income (unaudited). | |||||||||||||||||||||||
During the third quarter of 2024, the requirements for settlement accounting were met for one of our pension plans, resulting in a settlement charge of $5.9 million for the three months ended September 30, 2024.
15. 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 September 30, 2024 and December 31, 2023, we had issued stand-by letters of credit of $9.4 million and $9.9 million, respectively for the benefit of third parties.
We provide guarantees related to our future performance under BTAs for our renewable generation projects. At September 30, 2024 and December 31, 2023, our guarantees for multiple BTAs totaled $1,150.2 million and $646.1 million, respectively. The amount of each guaranty will decrease upon the substantial completion of the construction of the facilities. See ''- D. Other Matters - Generation Transition,'' below for more information.
B. Legal Proceedings. From time to time, various legal and regulatory claims and proceedings are pending or threatened against the Company and its subsidiaries. While the amounts claimed may be substantial, the Company is unable to predict with certainty the ultimate outcome of such claims and proceedings. The Company establishes reserves whenever it believes it to be appropriate for pending litigation matters. However, the actual results of resolving the pending litigation matters may be substantially higher than the amounts reserved. If one or more matters were decided against us, the effects could be material to
33
ITEM 1. FINANCIAL STATEMENTS (continued)
NiSource Inc.
Notes to Condensed Consolidated Financial Statements (unaudited) (continued)
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. Due to the inherent uncertainty of litigation, there can be no assurance that the resolution of any particular claim, proceeding or investigation would not have a material adverse effect on our results of operations, financial position or liquidity.
Other Claims and Proceedings. We are also party to other claims, regulatory and legal proceedings arising in the ordinary course of business in each state in which we have operations, and based upon an investigation of these matters and discussion with legal counsel, we believe the ultimate outcome of such other legal proceedings to be individually, or in aggregate, not material at this time.
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 majority of environmental assessment and remediation costs and asset retirement costs, further described below, to be recoverable through rates.
As of September 30, 2024 and December 31, 2023, we had recorded a liability of $92.6 million and $80.0 million, respectively, to cover environmental remediation at various sites. This liability is included in "Other accruals" and "Other noncurrent liabilities and deferred credits" in the Condensed Consolidated Balance Sheets (unaudited). We recognize costs associated with environmental remediation obligations when the incurrence of such costs is probable and the amounts can be reasonably estimated. The original estimates for remediation activities may differ materially from the amount ultimately expended. The actual future expenditures depend on many factors, including laws and regulations, the nature and extent of impact and the method of remediation. These expenditures are not currently estimable at some sites. We periodically adjust our liability as information is collected and estimates become more refined.
CERCLA. Our subsidiaries are potentially responsible parties at waste disposal sites under CERCLA 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. At this time, we cannot estimate the full cost of remediating properties that have not yet been investigated, but it is possible that the future costs could be material to the Condensed Consolidated Financial Statements (unaudited).
MGP. We maintain a program to identify and investigate former MGP sites where our subsidiaries or predecessors may have liability. The program has identified 51 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. We recorded an $11.2 million increase to the estimated future remediation costs as a result of the refresh completed in the second quarter of 2024. No material changes to the estimated future remediation costs were noted as a result of an internal quarterly review of environmental reserves completed as of September 30, 2024. Our total estimated liability related to the facilities subject to remediation was $87.9 million and $73.7 million at September 30, 2024 and December 31, 2023, respectively. The liability represents our best estimate of the probable cost to remediate the MGP sites. Our model indicates that it is reasonably possible that remediation costs could vary by as much as $16.4 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. NIPSCO continues to meet the compliance requirements established by the EPA for the regulation of CCRs. The CCR rule requirements currently in effect required 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.
34
ITEM 1. FINANCIAL STATEMENTS (continued)
NiSource Inc.
Notes to Condensed Consolidated Financial Statements (unaudited) (continued)
D. Other Matters.
35
ITEM 1. FINANCIAL STATEMENTS (continued)
NiSource Inc.
Notes to Condensed Consolidated Financial Statements (unaudited) (continued)
16. Accumulated Other Comprehensive Loss
The following tables display the components of Accumulated Other Comprehensive Loss, net of tax:
| (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 July 1, 2024 | $ | ( | $ | ( | $ | ( | $ | ( | |||||||||||||||
Other comprehensive income (loss) before reclassifications | ( | ||||||||||||||||||||||
| Amounts reclassified from accumulated other comprehensive loss | ( | ||||||||||||||||||||||
Net current-period other comprehensive income (loss) | ( | ||||||||||||||||||||||
| Balance as of September 30, 2024 | $ | ( | $ | ( | $ | ( | $ | ( | |||||||||||||||
(1)All amounts are net of tax. Amounts in parentheses indicate debits. | |||||||||||||||||||||||
| (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, 2024 | $ | ( | $ | ( | $ | ( | $ | ( | |||||||||||||||
| Other comprehensive income (loss) before reclassifications | ( | ||||||||||||||||||||||
| Amounts reclassified from accumulated other comprehensive loss | ( | ||||||||||||||||||||||
| Net current-period other comprehensive income (loss) | ( | ||||||||||||||||||||||
| Balance as of September 30, 2024 | $ | ( | $ | ( | $ | ( | $ | ( | |||||||||||||||
(1)All amounts are net of tax. Amounts in parentheses indicate debits.
| (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 July 1, 2023 | $ | ( | $ | ( | $ | ( | $ | ( | |||||||||||||||
| Other comprehensive income (loss) before reclassifications | ( | ( | ( | ( | |||||||||||||||||||
| Amounts reclassified from accumulated other comprehensive loss | |||||||||||||||||||||||
| Net current-period other comprehensive income (loss) | ( | ( | ( | ||||||||||||||||||||
| Balance as of September 30, 2023 | $ | ( | $ | ( | $ | ( | $ | ( | |||||||||||||||
(1)All amounts are net of tax. Amounts in parentheses indicate debits. | |||||||||||||||||||||||
| (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, 2023 | $ | ( | $ | ( | $ | ( | $ | ( | |||||||||||||||
| Other comprehensive income (loss) before reclassifications | ( | ( | ( | ||||||||||||||||||||
| Amounts reclassified from accumulated other comprehensive loss | |||||||||||||||||||||||
| Net current-period other comprehensive income (loss) | ( | ( | |||||||||||||||||||||
| Balance as of September 30, 2023 | $ | ( | $ | ( | $ | ( | $ | ( | |||||||||||||||
(1)All amounts are net of tax. Amounts in parentheses indicate debits.
36
ITEM 1. FINANCIAL STATEMENTS (continued)
NiSource Inc.
Notes to Condensed Consolidated Financial Statements (unaudited) (continued)
17. Business Segment Information
Our reportable segments reflect the manner in which our business is managed and our resources are allocated. Following the consummation of the NIPSCO Minority Interest Transaction, we revised how we evaluate results and allocate resources across our business with an increased focus on operating performance at the state level. Refer to Note 4, "Noncontrolling Interests," for additional information on the NIPSCO Minority Interest Transaction. Our operations are now evaluated through two primary reportable segments, Columbia Operations and NIPSCO Operations. Columbia Operations aggregates the results of the fully regulated and wholly owned subsidiaries of NiSource Gas Distribution Group, Inc. (a holding company that owns Columbia of Kentucky, Columbia of Maryland, Columbia of Ohio, Columbia of Pennsylvania, and Columbia of Virginia). Each Columbia distribution company is an operating segment which we aggregate to form the Columbia Operations reportable segment. NIPSCO Operations includes the results of NIPSCO Holdings I and its majority-owned subsidiaries, including NIPSCO, which has fully regulated gas and electric operations in Northwest Indiana.
The remainder of our operations, which are not significant enough on a stand-alone basis to warrant treatment as a reportable segment, are presented as "Corporate and Other" and primarily are comprised of interest expense on holding company debt, and unallocated corporate costs and activities. Refer to Note 3, "Revenue Recognition," for additional information on our segments and their sources of revenues. The following table provides information about our reportable segments. Our CODM uses operating income as the primary measurement for each of the reported segments and makes decisions on financing, 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.
37
ITEM 1. FINANCIAL STATEMENTS (continued)
NiSource Inc.
Notes to Condensed Consolidated Financial Statements (unaudited) (continued)
| Three Months Ended September 30, | Nine Months Ended September 30, | ||||||||||||||||||||||
| (in millions) | 2024 | 2023 | 2024 | 2023 | |||||||||||||||||||
| Operating Revenues | |||||||||||||||||||||||
Columbia Operations | |||||||||||||||||||||||
| Unaffiliated | $ | $ | $ | $ | |||||||||||||||||||
| Intersegment | |||||||||||||||||||||||
| Total | |||||||||||||||||||||||
NIPSCO Operations | |||||||||||||||||||||||
| Unaffiliated | |||||||||||||||||||||||
| Intersegment | |||||||||||||||||||||||
| Total | |||||||||||||||||||||||
| Corporate and Other | |||||||||||||||||||||||
| Unaffiliated | |||||||||||||||||||||||
| Intersegment | |||||||||||||||||||||||
| Total | |||||||||||||||||||||||
| Eliminations | ( | ( | ( | ( | |||||||||||||||||||
| Consolidated Operating Revenues | $ | $ | $ | $ | |||||||||||||||||||
Operating Income | |||||||||||||||||||||||
Columbia Operations | $ | $ | $ | $ | |||||||||||||||||||
NIPSCO Operations | |||||||||||||||||||||||
| Corporate and Other | |||||||||||||||||||||||
| Consolidated Operating Income | $ | $ | $ | $ | |||||||||||||||||||
The following table provides information about the assets of our reportable segments included in the Condensed Consolidated Balance Sheet (unaudited):
(in millions) | September 30, 2024 | December 31, 2023 | |||||||||
Assets | |||||||||||
Columbia Operations | $ | $ | |||||||||
NIPSCO Operations | |||||||||||
Corporate and Other | |||||||||||
Consolidated Assets | $ | $ | |||||||||
Information about our reportable segments for the nine months ended September 30, 2023, as well as for the period ended December 31, 2023 has been recast to align with the current year's presentation.
38
ITEM 1. FINANCIAL STATEMENTS (continued)
NiSource Inc.
Notes to Condensed Consolidated Financial Statements (unaudited) (continued)
18. Other, Net
The following table displays the components of Other, Net included on the Condensed Statements of Consolidated Income (unaudited):
| Three Months Ended September 30, | Nine Months Ended September 30, | ||||||||||||||||||||||
| (in millions) | 2024 | 2023 | 2024 | 2023 | |||||||||||||||||||
| Interest income | $ | $ | $ | $ | |||||||||||||||||||
| AFUDC equity | |||||||||||||||||||||||
Pension and other postretirement non-service cost | ( | ( | ( | ( | |||||||||||||||||||
Miscellaneous | ( | ( | ( | ( | |||||||||||||||||||
| Total Other, net | $ | $ | ( | $ | $ | ||||||||||||||||||
39
ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS
NiSource Inc.
| Index | Page | ||||
40
ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (continued)
NiSource Inc.
EXECUTIVE SUMMARY
This Management's Discussion and Analysis of Financial Condition and Results of Operations ("Management’s Discussion") includes management’s analysis of past financial results and certain potential factors that may affect future results, potential future risks and approaches that may be used to manage those risks. See "Note regarding forward-looking statements" at the beginning of this report for a list of factors that may cause results to differ materially.
Management's Discussion is designed to provide an understanding of our operations and financial performance and should be read in conjunction with our Annual Report on Form 10-K for the fiscal year ended December 31, 2023.
We are an energy holding company under the Public Utility Holding Company Act of 2005 whose utility subsidiaries are fully regulated natural gas and electric utility companies serving customers in six states. We generate substantially all of our operating income through these rate-regulated businesses, which are summarized for financial reporting purposes into two primary reportable segments: Columbia Operations and NIPSCO Operations. Refer to ''Note 17, "Business Segment Information," for further discussion of our business segments.
Our goal is to develop strategies that benefit all stakeholders as we (i) focus on long-term infrastructure investment and safety programs to better serve our customers, (ii) align our tariff structures with our cost structure, and (iii) address changing customer energy demand. These strategies focus on improving safety and reliability, enhancing customer experience, pursuing regulatory and legislative initiatives to increase accessibility for customers currently not on our gas and electric service, ensuring customer affordability and reducing emissions while generating sustainable returns. The safety of our customers, communities and employees remains our focus. Serving as a guiding practice for our SMS, NiSource is certified in conformance to the American Petroleum Institute Recommended Practice 1173, which is the foundation to our journey towards operational excellence. We continue to make advancements in key strategic initiatives, described in further detail below.
Energy Transition: We are advancing our energy transition strategy, primarily through the continuation and enhancement of existing programs, such as retiring and replacing remaining coal-fired electric generation by 2028 with a balanced mix of low- or zero-emission electric generation, ongoing pipe replacement and modernization programs, and deployment of advanced leak detection and repair. Our electric generation transition, initiated through the NIPSCO 2018 Integrated Resource Plan ("2018 Plan") is well underway, and we are continually adjusting to the dynamic energy landscape. As of September 30, 2024, we have executed and received IURC approval for BTAs and PPAs for wind, solar and solar plus storage projects, with a combined nameplate capacity of 1,950 MW and 1,400 MW, respectively, under the 2018 Plan. In January 2024, the IURC approved full ownership of the Cavalry and Dunns Bridge II projects. In August 2024 the IURC approved full ownership of the Gibson and Fairbanks projects and modification of the cost of the Fairbanks project as contemplated in the contractual actions. Full ownership of these projects allows NIPSCO to leverage provisions of the IRA, monetize renewable tax credits more effectively, and provide enhanced benefits to customers as compared to the previous tax equity partnership structure approved by the IURC. In May 2024, the Cavalry project was placed in service. We remain on track to retire R.M Schahfer's remaining two coal units by the end of 2025. For additional information, see "Results and Discussion of Segment Operations - NIPSCO Operations," in this Management's Discussion.
In 2021, we announced and filed with the IURC the Preferred Energy Resource Plan associated with our 2021 Integrated Resource Plan ("2021 Plan"). The 2021 Plan affirms plans to retire the coal unit at the Michigan City Generating Station by the end of 2028. The 2021 Plan calls for the replacement of the retiring units with a diverse portfolio of resources including demand side management resources, incremental solar, stand-alone energy storage and upgrades to existing facilities at the Sugar Creek Generating Station, among other steps. In the first half of 2024, Sugar Creek completed an Advanced Gas Path Tech upgrade that enhanced its overall production capabilities by an estimated 68 MW. Additionally, the 2021 Plan calls for a new natural gas peaking facility to replace existing vintage gas peaking facilities at the R.M. Schahfer Generating Station to support system reliability and resiliency, and upgrades to the electric transmission system. In September of 2023, we filed a request for issuance of a certificate of public convenience and necessity for an approximately 400 MW natural gas peaking generation facility with the IURC, which was approved in October of 2024. The planned retirement of the two vintage gas peaking facilities at the R.M. Schahfer Generating Station is also expected to occur by the end of 2028. Final retirement dates for these units, as well as Michigan City, will be subject to MISO approval.
NIPSCO’s 2024 Integrated Resource Plan ("2024 Plan") is currently in-progress and formal stakeholder engagement began in the second quarter. The 2024 Plan will inform future generation investments needed to ensure reliability for NIPSCO’s customers and will incorporate factors such as anticipated load growth from data centers and other economic development
41
ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (continued)
NiSource Inc.
opportunities, new EPA emissions rules, and evolving MISO resource accreditation rules. The 2024 Plan will be submitted to the IURC in December 2024 and will include an updated Preferred Energy Resource Plan. We have seen an acceleration of customer interest in our northern Indiana service territory in the form of data center development. We believe data center development can enhance our local tax base, diversify the employment base across the state of Indiana, and provide greater value to existing customers and shareholders. We are evaluating the potential for data center development in our service territory, including ways to effectively manage the potential power demand, generation sources, and transmission capabilities to meet potential load growth from any data center customer, while at the same time focusing on our environmental goals. We expect that management of load growth would require new generation and transmission capabilities. We plan to move as efficiently as possible while maintaining the integrity of our commercial, planning, regulatory, procurement and operational execution processes.
We continue to enhance safety and reduce methane emissions on our gas systems through modernization programs and utilization of advanced leak detection and repair. In addition, we plan to advance other low- or zero-emission energy resources and technologies, such as hydrogen and renewable natural gas.
NIPSCO Minority Interest Transaction: On December 31, 2023, contemporaneously with the closing of the NIPSCO Minority Interest Transaction, Blackstone, NIPSCO Holdings I, NIPSCO Holdings II, and NiSource entered into an Amended and Restated Limited Liability Company Agreement (the "LLC Agreement") of NIPSCO Holdings II. On January 31, 2024, BIP transferred a 4.5% equity interest in NIPSCO Holdings II to BIP Blue Buyer VCOC L.L.C., a Delaware limited liability company and also an affiliate of Blackstone. Effective upon the closing of this transfer, the members of NIPSCO Holdings II entered into a Second Amended and Restated Limited Liability Company Operating Agreement of NIPSCO Holdings II (the "Amended LLC Agreement"). The two affiliates of Blackstone must vote their equity holdings under the Amended LLC Agreement as one investor. Refer to Note 4, "Noncontrolling Interests," for more information on this transaction.
Transformation: Our enterprise-wide transformation roadmap focuses on operational excellence, safety, operation and maintenance management, and unlocking efficiencies. We are committed to identifying and implementing initiatives that will enable us to streamline work and improve logistics company-wide. These efforts include investments in proven technologies backed with standardized processes that will change the way we plan, schedule, and execute work in the field and how we engage and provide service to our customers. Taken together, all of our optimization initiatives will prioritize safety and continue to optimize our long-term growth profile. We are making progress towards our transformation goals with a successful completion of the first phase of our WAM program, an enterprise resource planning system that will optimize the scheduling, dispatch, and execution of our field operations. This phase of the program implemented the solution within our electric distribution operations, while our second phase for gas distribution operations is anticipated to be completed by the third quarter of 2025.
Economic Environment: We continue to monitor risks related to increasing order and delivery lead times for construction and other materials, potential unavailability of materials due to global shortages in raw materials, and decreased construction labor productivity in the event of disruptions in the availability of materials. We continue to see increasing prices associated with environmental remediation services and certain materials and supplies. To the extent that work delays occur or our costs increase, our business operations, results of operations, cash flows, and financial condition could be materially adversely affected.
We are faced with increased competition for employee and contractor talent in the current labor market which has resulted in increased costs to attract and retain talent. We are ensuring that we use all internal human capital programs (development, leadership enablement programs, succession, performance management) to promote retention of our current employees along with having a competitive and attractive employee value proposition for potential recruits. With a focus on workforce planning we continue to evaluate talent needs and flexible work arrangements where possible to support a broader talent footprint for sourcing needed talent.
We continue to evaluate our financing plan to manage interest expense and exposure to rates. For more information on interest rate risk, see "Market Risk Disclosures".
42
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 nine months ended September 30, 2024 and 2023 are presented below:
Three Months Ended September 30, | Nine Months Ended September 30, | ||||||||||||||||||||||||||||||||||
| (in millions, except per share amounts) | 2024 | 2023 | Favorable (Unfavorable) | 2024 | 2023 | Favorable (Unfavorable) | |||||||||||||||||||||||||||||
| Operating Revenues | $ | 1,076.3 | $ | 1,027.4 | $ | 48.9 | $ | 3,867.3 | $ | 4,083.4 | $ | (216.1) | |||||||||||||||||||||||
| Operating Expenses | |||||||||||||||||||||||||||||||||||
| Cost of energy | 165.9 | 181.3 | 15.4 | 755.6 | 1,198.3 | 442.7 | |||||||||||||||||||||||||||||
Depreciation expense | 269.5 | 210.9 | (58.6) | 765.1 | 650.9 | (114.2) | |||||||||||||||||||||||||||||
Other Operating Expenses | 422.6 | 402.2 | (20.4) | 1,307.9 | 1,301.3 | (6.6) | |||||||||||||||||||||||||||||
| Total Operating Expenses | 858.0 | 794.4 | (63.6) | 2,828.6 | 3,150.5 | 321.9 | |||||||||||||||||||||||||||||
| Operating Income | 218.3 | 233.0 | (14.7) | 1,038.7 | 932.9 | 105.8 | |||||||||||||||||||||||||||||
| Total Other Deductions, Net | (105.4) | (130.8) | 25.4 | (328.8) | (346.7) | 17.9 | |||||||||||||||||||||||||||||
| Income Taxes | 15.9 | 3.8 | (12.1) | 109.5 | 103.7 | (5.8) | |||||||||||||||||||||||||||||
| Net Income | 97.0 | 98.4 | (1.4) | 600.4 | 482.5 | 117.9 | |||||||||||||||||||||||||||||
| Net income attributable to noncontrolling interest | 11.3 | 13.3 | 2.0 | 63.9 | 5.6 | (58.3) | |||||||||||||||||||||||||||||
| Net Income Attributable to NiSource | 85.7 | 85.1 | 0.6 | 536.5 | 476.9 | 59.6 | |||||||||||||||||||||||||||||
| Preferred dividends and redemption premium | — | (8.1) | 8.1 | (20.7) | (40.8) | 20.1 | |||||||||||||||||||||||||||||
| Net Income Available to Common Shareholders | 85.7 | 77.0 | 8.7 | 515.8 | 436.1 | 79.7 | |||||||||||||||||||||||||||||
| Earnings Per Share | |||||||||||||||||||||||||||||||||||
Basic Earnings Per Share | $ | 0.19 | $ | 0.19 | $ | — | $ | 1.15 | $ | 1.05 | $ | 0.10 | |||||||||||||||||||||||
| Diluted Earnings Per Share | $ | 0.19 | $ | 0.17 | $ | 0.02 | $ | 1.14 | $ | 0.98 | $ | 0.16 | |||||||||||||||||||||||
The majority of the cost of energy in the Columbia Operations and NIPSCO Operations segments are tracked costs that are passed through directly to the customer, resulting in an equal and offsetting amount reflected in operating revenues.
The increase in net income available to common shareholders for the three and nine months ended September 30, 2024 was primarily due to higher revenues, net of cost of energy, driven by our continued investment in safety, reliability and low or zero emission generation as well as increased AFUDC Equity, reported in Other Deductions, Net, primarily related to the mechanical completion of NIPSCO's Cavalry and Dunns Bridge II projects. Additionally, net income available to common shareholders increased due to the elimination of the preferred stock dividends following the redemption of both the Series A and B preferred stock. For the three and nine months ended September 30, 2024, the increase in net income available to common shareholders is primarily offset by higher depreciation expense attributed to our planned capital expenditures and higher interest expense. Increased net income attributable to noncontrolling interest following the consummation of the NIPSCO Minority Interest Transaction reduces net income available to common shareholders for the nine months ended September 30, 2024 . See Note 6, "Equity," in the Notes to the Condensed Consolidated Financial Statements (unaudited) for additional information.
For additional information on operating income variance drivers see "Results and Discussion of Segment Operations" for Columbia Operations and NIPSCO Operations in this Management's Discussion.
Income Taxes
Refer to Note 13, "Income Taxes," in the Notes to the Condensed Consolidated Financial Statements (unaudited) for information on income taxes and the change in the effective tax rates.
We continue to monitor and evaluate the impacts of final or proposed income tax regulations issued on provisions of the IRA including but not limited to renewable energy tax credits.
43
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
In response to the NIPSCO Minority Interest Transaction, our operations are now evaluated through two primary reportable segments, Columbia Operations and NIPSCO Operations. Our historical segment disclosures have been recast to be consistent with the current presentation. Columbia Operations aggregates the results of the fully regulated and wholly owned subsidiaries of NiSource Gas Distribution Group, Inc. Each Columbia distribution company is an operating segment which we aggregate to form the Columbia Operations reportable segment. NIPSCO Operations aggregates the results of NIPSCO Holdings I, and its majority-owned subsidiaries, including NIPSCO, which has both fully regulated gas and electric operations in Northwest Indiana. The remainder of our operations, which are not significant enough on a stand-alone basis to warrant treatment as a reportable segment, are presented as "Corporate and Other" within the Notes to the Condensed Consolidated Financial Statements (unaudited) and primarily are comprised of interest expense on holding company debt, and unallocated corporate costs and activities.
44
ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (continued)
NiSource Inc.
Columbia Operations
Financial and operational data for the Columbia Operations segment for the three and nine months ended September 30, 2024 and 2023 are presented below.
Three Months Ended September 30, | Nine Months Ended September 30, | ||||||||||||||||||||||||||||||||||
| (in millions) | 2024 | 2023 | Favorable (Unfavorable) | 2024 | 2023 | Favorable (Unfavorable) | |||||||||||||||||||||||||||||
| Operating Revenues | $ | 426.7 | $ | 414.0 | $ | 12.7 | $ | 1,874.1 | $ | 1,990.6 | $ | (116.5) | |||||||||||||||||||||||
| Operating Expenses | |||||||||||||||||||||||||||||||||||
| Cost of energy | 34.2 | 44.6 | 10.4 | 319.3 | 477.2 | 157.9 | |||||||||||||||||||||||||||||
| Operation and maintenance | 202.9 | 176.6 | (26.3) | 604.9 | 584.4 | (20.5) | |||||||||||||||||||||||||||||
| Depreciation and amortization | 103.0 | 94.8 | (8.2) | 300.6 | 274.7 | (25.9) | |||||||||||||||||||||||||||||
| Other taxes | 45.4 | 43.4 | (2.0) | 149.5 | 146.8 | (2.7) | |||||||||||||||||||||||||||||
| Total Operating Expenses | 385.5 | 359.4 | (26.1) | 1,374.3 | 1,483.1 | 108.8 | |||||||||||||||||||||||||||||
| Operating Income | $ | 41.2 | $ | 54.6 | $ | (13.4) | $ | 499.8 | $ | 507.5 | $ | (7.7) | |||||||||||||||||||||||
| Revenues | |||||||||||||||||||||||||||||||||||
| Residential | $ | 299.2 | $ | 283.6 | $ | 15.6 | $ | 1,303.4 | $ | 1,351.3 | $ | (47.9) | |||||||||||||||||||||||
| Commercial | 79.2 | 78.9 | 0.3 | 402.4 | 441.6 | (39.2) | |||||||||||||||||||||||||||||
| Industrial | 32.3 | 30.2 | 2.1 | 106.0 | 103.2 | 2.8 | |||||||||||||||||||||||||||||
| Off-System | 7.2 | 9.8 | (2.6) | 30.5 | 49.9 | (19.4) | |||||||||||||||||||||||||||||
| Other | 8.8 | 11.5 | (2.7) | 31.8 | 44.6 | (12.8) | |||||||||||||||||||||||||||||
| Total | $ | 426.7 | $ | 414.0 | $ | 12.7 | $ | 1,874.1 | $ | 1,990.6 | $ | (116.5) | |||||||||||||||||||||||
| Sales and Transportation (MMDth) | |||||||||||||||||||||||||||||||||||
| Residential | 8.3 | 8.7 | (0.4) | 102.0 | 104.1 | (2.1) | |||||||||||||||||||||||||||||
| Commercial | 12.2 | 12.9 | (0.7) | 85.0 | 84.2 | 0.8 | |||||||||||||||||||||||||||||
| Industrial | 70.9 | 64.4 | 6.5 | 207.9 | 188.7 | 19.2 | |||||||||||||||||||||||||||||
| Off-System | 4.6 | 7.0 | (2.4) | 17.8 | 25.6 | (7.8) | |||||||||||||||||||||||||||||
| Other | — | — | — | 0.2 | 0.2 | — | |||||||||||||||||||||||||||||
| Total | 96.0 | 93.0 | 3.0 | 412.9 | 402.8 | 10.1 | |||||||||||||||||||||||||||||
Heating Degree Days(1) | 28 | 35 | (7) | 2,659 | 2,756 | (97) | |||||||||||||||||||||||||||||
Normal Heating Degree Days(1) | 53 | 53 | — | 3,310 | 3,292 | 18 | |||||||||||||||||||||||||||||
% Warmer than Normal | (47) | % | (34) | % | (20) | % | (16) | % | |||||||||||||||||||||||||||
% Warmer than prior year | (20) | % | (4) | % | |||||||||||||||||||||||||||||||
Columbia Operations Customers | |||||||||||||||||||||||||||||||||||
| Residential | 2,202,206 | 2,189,333 | 12,873 | ||||||||||||||||||||||||||||||||
| Commercial | 186,087 | 185,821 | 266 | ||||||||||||||||||||||||||||||||
| Industrial | 1,975 | 1,982 | (7) | ||||||||||||||||||||||||||||||||
| Other | 4 | 3 | 1 | ||||||||||||||||||||||||||||||||
| Total | 2,390,272 | 2,377,139 | 13,133 | ||||||||||||||||||||||||||||||||
(1) Heating degree figures represent averages of the five jurisdictions served by Columbia Operations.
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.
45
ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (continued)
NiSource Inc.
Columbia Operations
The underlying reasons for changes in our operating revenues for the three and nine months ended September 30, 2024 compared to the same period in 2023 are presented below.
| Favorable (Unfavorable) | |||||||||||
Changes in Operating Revenues (in millions) | Three Months Ended September 30, 2024 vs 2023 | Nine Months Ended September 30, 2024 vs 2023 | |||||||||
| New rates from base rate proceedings and regulatory capital programs | $ | 19.1 | $ | 71.3 | |||||||
The effects of customer usage | (1.5) | 7.9 | |||||||||
| The effects of customer growth | 1.4 | 5.0 | |||||||||
The effects of weather in 2024 compared to 2023 | (1.0) | (6.3) | |||||||||
| Other | (0.2) | (3.6) | |||||||||
| Change in operating revenues (before cost of energy and other tracked items) | $ | 17.8 | $ | 74.3 | |||||||
| Operating revenues offset in operating expense | |||||||||||
| Lower cost of energy billed to customers | (10.3) | (157.8) | |||||||||
Higher (lower) tracker deferrals within operation and maintenance, depreciation, and tax | 5.2 | (33.0) | |||||||||
| Total change in operating revenues | $ | 12.7 | $ | (116.5) | |||||||
Weather
In general, we calculate the weather-related revenue variance based on changing customer demand driven by weather variance from normal heating degree days, net of weather normalization mechanisms. Our composite heating degree days reported do not directly correlate to the weather-related dollar impact on the results of Columbia 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.
Throughput
The increase in total volumes for the three months ended September 30, 2024, compared to the same period in 2023, is primarily attributable to increased industrial usage offset by off-system sales.
The increase in total volumes for the nine months ended September 30, 2024, compared to the same period in 2023, is primarily attributable to increased industrial usage offset by off-system sales.
Commodity Price Impact
Cost of energy for the Columbia Operations segment is principally comprised of the cost of natural gas used while providing transportation and distribution services to customers. All Columbia Operations companies have state-approved recovery mechanisms that provide a means for full recovery of prudently incurred gas costs. These are tracked costs that are passed through directly to the customer, and the gas costs included in revenues are matched with the gas cost expense recorded in the period. The difference is recorded on the Condensed Consolidated Balance Sheets (unaudited) as under-recovered or over-recovered gas cost to be included in future customer billings. Therefore, increases in these tracked operating expenses are offset by increases in operating revenues and have essentially no impact on net income.
Certain of the Columbia 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.
46
ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (continued)
NiSource Inc.
Columbia Operations
The underlying reasons for changes in our operating expenses for the three and nine months ended September 30, 2024 compared to the same period in 2023 are presented below.
| Favorable (Unfavorable) | |||||||||||
Changes in Operating Expenses (in millions) | Three Months Ended September 30, 2024 vs 2023 | Nine Months Ended September 30, 2024 vs 2023 | |||||||||
| Higher employee and administrative related expenses | $ | (22.6) | $ | (40.6) | |||||||
| Higher depreciation and amortization expense | (8.1) | (25.8) | |||||||||
Higher materials and supplies expense | (2.8) | (4.1) | |||||||||
| Higher property tax | (0.1) | (2.7) | |||||||||
| Other | 2.4 | (8.8) | |||||||||
| Change in operating expenses (before cost of energy and other tracked items) | $ | (31.2) | $ | (82.0) | |||||||
| Operating expenses offset in operating revenue | |||||||||||
| Lower cost of energy billed to customers | 10.3 | 157.8 | |||||||||
(Lower) higher tracker deferrals within operation and maintenance, depreciation, and tax | (5.2) | 33.0 | |||||||||
| Total change in operating expense | $ | (26.1) | $ | 108.8 | |||||||
47
ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (continued)
NiSource Inc.
NIPSCO Operations
Financial and operational data for the NIPSCO Operations segment, which services both gas and electric customers, for the three and nine months ended September 30, 2024 and 2023 are presented below.
Three Months Ended September 30, | Nine Months Ended September 30, | ||||||||||||||||||||||||||||||||||
| (in millions) | 2024 | 2023 | Favorable (Unfavorable) | 2024 | 2023 | Favorable (Unfavorable) | |||||||||||||||||||||||||||||
NIPSCO Operations | |||||||||||||||||||||||||||||||||||
Operating Revenues | $ | 652.9 | $ | 616.6 | $ | 36.3 | $ | 2,003.0 | $ | 2,102.1 | $ | (99.1) | |||||||||||||||||||||||
| Operating Expenses | |||||||||||||||||||||||||||||||||||
| Cost of energy | 131.7 | 136.7 | 5.0 | 436.3 | 721.2 | 284.9 | |||||||||||||||||||||||||||||
| Operation and maintenance | 177.7 | 186.7 | 9.0 | 556.5 | 580.2 | 23.7 | |||||||||||||||||||||||||||||
| Depreciation and amortization | 156.8 | 105.7 | (51.1) | 432.5 | 344.1 | (88.4) | |||||||||||||||||||||||||||||
| Gain on sale of assets | — | — | — | (0.1) | (0.1) | — | |||||||||||||||||||||||||||||
| Other taxes | 15.4 | 14.4 | (1.0) | 47.8 | 42.8 | (5.0) | |||||||||||||||||||||||||||||
| Total Operating Expenses | 481.6 | 443.5 | (38.1) | 1,473.0 | 1,688.2 | 215.2 | |||||||||||||||||||||||||||||
Operating Income | $ | 171.3 | $ | 173.1 | $ | (1.8) | $ | 530.0 | $ | 413.9 | $ | 116.1 | |||||||||||||||||||||||
Three Months Ended September 30, | Nine Months Ended September 30, | ||||||||||||||||||||||||||||||||||
| (in millions) | 2024 | 2023 | Favorable (Unfavorable) | 2024 | 2023 | Favorable (Unfavorable) | |||||||||||||||||||||||||||||
| NIPSCO Electric | |||||||||||||||||||||||||||||||||||
Revenues | |||||||||||||||||||||||||||||||||||
| Residential | $ | 197.9 | $ | 176.0 | $ | 21.9 | $ | 498.6 | $ | 449.2 | $ | 49.4 | |||||||||||||||||||||||
| Commercial | 172.7 | 156.6 | 16.1 | 470.0 | 437.6 | 32.4 | |||||||||||||||||||||||||||||
| Industrial | 125.1 | 116.0 | 9.1 | 361.1 | 363.3 | (2.2) | |||||||||||||||||||||||||||||
| Wholesale | 14.9 | 15.4 | (0.5) | 32.4 | 25.5 | 6.9 | |||||||||||||||||||||||||||||
| Other | 28.5 | 35.1 | (6.6) | 80.2 | 85.3 | (5.1) | |||||||||||||||||||||||||||||
| Total | $ | 539.1 | $ | 499.1 | $ | 40.0 | $ | 1,442.3 | $ | 1,360.9 | $ | 81.4 | |||||||||||||||||||||||
Sales (GWh) | |||||||||||||||||||||||||||||||||||
| Residential | 1,079.4 | 1,034.7 | 44.7 | 2,673.1 | 2,540.6 | 132.5 | |||||||||||||||||||||||||||||
| Commercial | 1,044.7 | 1,011.0 | 33.7 | 2,850.3 | 2,743.7 | 106.6 | |||||||||||||||||||||||||||||
| Industrial | 2,106.3 | 2,023.7 | 82.6 | 5,884.1 | 5,955.3 | (71.2) | |||||||||||||||||||||||||||||
Wholesale | 307.8 | 288.4 | 19.4 | 755.1 | 431.1 | 324.0 | |||||||||||||||||||||||||||||
| Other | 19.9 | 17.6 | 2.3 | 63.0 | 58.2 | 4.8 | |||||||||||||||||||||||||||||
| Total | 4,558.1 | 4,375.4 | 182.7 | 12,225.6 | 11,728.9 | 496.7 | |||||||||||||||||||||||||||||
| Cooling Degree Days | 556 | 475 | 81 | 882 | 681 | 201 | |||||||||||||||||||||||||||||
| Normal Cooling Degree Days | 590 | 573 | 17 | 838 | 820 | 18 | |||||||||||||||||||||||||||||
% Warmer (Colder) than Normal | (6) | % | (17) | % | 5 | % | (17) | % | |||||||||||||||||||||||||||
% Warmer than prior year | 17 | % | 30 | % | |||||||||||||||||||||||||||||||
NIPSCO Electric Customers | |||||||||||||||||||||||||||||||||||
| Residential | 429,382 | 426,054 | 3,328 | ||||||||||||||||||||||||||||||||
| Commercial | 59,056 | 58,556 | 500 | ||||||||||||||||||||||||||||||||
| Industrial | 2,116 | 2,126 | (10) | ||||||||||||||||||||||||||||||||
| Wholesale | 707 | 708 | (1) | ||||||||||||||||||||||||||||||||
| Other | 2 | 3 | (1) | ||||||||||||||||||||||||||||||||
| Total | 491,263 | 487,447 | 3,816 | ||||||||||||||||||||||||||||||||
48
ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (continued)
NiSource Inc.
NIPSCO Operations
| Three Months Ended September 30, | Nine Months Ended September 30, | ||||||||||||||||||||||||||||||||||
| (in millions) | 2024 | 2023 | Favorable (Unfavorable) | 2024 | 2023 | Favorable (Unfavorable) | |||||||||||||||||||||||||||||
NIPSCO Gas | |||||||||||||||||||||||||||||||||||
Revenues | |||||||||||||||||||||||||||||||||||
| Residential | $ | 66.8 | $ | 69.1 | $ | (2.3) | $ | 357.5 | $ | 477.4 | $ | (119.9) | |||||||||||||||||||||||
| Commercial | 28.5 | 30.1 | (1.6) | 134.0 | 185.8 | (51.8) | |||||||||||||||||||||||||||||
| Industrial | 16.4 | 16.1 | 0.3 | 56.3 | 66.4 | (10.1) | |||||||||||||||||||||||||||||
| Other | 2.1 | 2.2 | (0.1) | 12.9 | 11.6 | 1.3 | |||||||||||||||||||||||||||||
| Total | $ | 113.8 | $ | 117.5 | $ | (3.7) | $ | 560.7 | $ | 741.2 | $ | (180.5) | |||||||||||||||||||||||
Sales and Transportation Volumes (MMDth) | |||||||||||||||||||||||||||||||||||
| Residential | 3.5 | 3.7 | (0.2) | 39.1 | 41.5 | (2.4) | |||||||||||||||||||||||||||||
| Commercial | 4.9 | 5.0 | (0.1) | 29.2 | 30.0 | (0.8) | |||||||||||||||||||||||||||||
| Industrial | 60.5 | 61.8 | (1.3) | 192.3 | 195.5 | (3.2) | |||||||||||||||||||||||||||||
| Total | 68.9 | 70.4 | (1.5) | 260.6 | 267.0 | (6.4) | |||||||||||||||||||||||||||||
| Heating Degree Days | 33 | 59 | (26) | 3,127 | 3,313 | (186) | |||||||||||||||||||||||||||||
| Normal Heating Degree Days | 79 | 79 | 0 | 3,860 | 3,817 | 43 | |||||||||||||||||||||||||||||
% Warmer than Normal | (58) | % | (25) | % | (19) | % | (13) | % | |||||||||||||||||||||||||||
% Warmer than prior year | (44) | % | (6) | % | |||||||||||||||||||||||||||||||
NIPSCO Gas Customers | |||||||||||||||||||||||||||||||||||
| Residential | 797,711 | 790,913 | 6,798 | ||||||||||||||||||||||||||||||||
| Commercial | 66,251 | 65,821 | 430 | ||||||||||||||||||||||||||||||||
| Industrial | 2,739 | 2,812 | (73) | ||||||||||||||||||||||||||||||||
| Total | 866,701 | 859,546 | 7,155 | ||||||||||||||||||||||||||||||||
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.
49
ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (continued)
NiSource Inc.
NIPSCO Operations
The underlying reasons for changes in our operating revenues for the three and nine months ended September 30, 2024 compared to the same period in 2023 are presented below.
| Favorable (Unfavorable) | |||||||||||
Changes in Operating Revenues (in millions) | Three Months Ended September 30, 2024 vs 2023 | Nine Months Ended September 30, 2024 vs 2023 | |||||||||
New rates from base rate proceedings, regulatory capital and DSM programs | $ | 41.9 | $ | 186.2 | |||||||
Renewable JV revenue, fully offset by JV operating expense | 6.0 | 16.6 | |||||||||
The effects of customer growth | 3.2 | 8.2 | |||||||||
The effects of customer usage | (0.5) | 7.0 | |||||||||
The effects of weather in 2024 compared to 2023 | 3.3 | (1.9) | |||||||||
| Other | 0.2 | 2.9 | |||||||||
| Change in operating revenues (before cost of energy and other tracked items) | $ | 54.1 | $ | 219.0 | |||||||
| Operating revenues offset in operating expense | |||||||||||
Lower cost of energy billed to customers | (5.0) | (284.9) | |||||||||
Lower tracker deferrals within operation and maintenance, depreciation and tax | (12.8) | (33.2) | |||||||||
| Total change in operating revenues | $ | 36.3 | $ | (99.1) | |||||||
Weather
The results of operations for the NIPSCO Operations segment include income from both electric and gas service lines. In general, we calculate the weather-related revenue variance based on changing customer demand driven by weather variance from normal cooling degree days and normal heating degree days, net of weather normalization mechanisms. Our composite cooling and heating degree days reported do not directly correlate to the weather-related dollar impact on the results of NIPSCO Operations. Cooling and 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 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 cooling and heating degree day comparison.
Sales
The increase in total volumes sold to electric customers for the three months ended September 30, 2024 compared to the same period in 2023 was primarily attributable to increased usage across all customer classes.
The increase in total volumes sold to electric customers for the nine months ended September 30, 2024 compared to the same period in 2023 was primarily attributable to increased usage by wholesale, residential and commercial customers offset by decreased usage by industrial customers.
The decrease in total volumes sold to gas customers for the three and nine months ended September 30, 2024 compared to the same period in 2023 was primarily attributable to decreased usage by industrial and residential customers.
Commodity Price Impact
Cost of energy for the NIPSCO Operations segment's electric activities is principally comprised of the cost of coal, natural gas purchased for internal generation of electricity, and the cost of power purchased from generators of electricity for its generation and transmission activities. For its gas distribution activities, NIPSCO Operations' cost of energy is principally comprised of the cost of natural gas used while providing transportation and distribution services to customers. NIPSCO Operations has state-approved recovery mechanisms that provide a means for full recovery of prudently incurred costs of energy. The majority of these costs of energy are passed through directly to the customer, and the costs of energy included in operating revenues are matched with the cost of energy expense recorded in the period. The difference is recorded on the Condensed Consolidated Balance Sheets (unaudited) as under-recovered or over-recovered fuel and gas costs to be included in future customer billings. Therefore, increases in these tracked operating expenses are offset by increases in operating revenues and have essentially no impact on net income.
50
ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (continued)
NiSource Inc.
NIPSCO Operations
The underlying reasons for changes in our operating expenses for the three and nine months ended September 30, 2024 compared to the same period in 2023 are presented below.
| Favorable (Unfavorable) | |||||||||||
Changes in Operating Expenses (in millions) | Three Months Ended September 30, 2024 vs 2023 | Nine Months Ended September 30, 2024 vs 2023 | |||||||||
Higher depreciation and amortization expense driven by new base rates | $ | (52.3) | $ | (82.8) | |||||||
Higher employee and administrative expenses | (2.2) | (17.2) | |||||||||
Renewable JV operating expenses, partially offset by JV operating revenues | 0.7 | (15.5) | |||||||||
Effects of environmental obligations | (0.5) | (4.9) | |||||||||
| (Higher) lower materials and supplies costs | (0.2) | 9.7 | |||||||||
(Higher) lower outside services expenses primarily related to lower generation-related maintenance | (4.3) | 3.2 | |||||||||
| Other | 2.9 | 4.6 | |||||||||
| Change in operating expenses (before cost of energy and other tracked items) | $ | (55.9) | $ | (102.9) | |||||||
| Operating expenses offset in operating revenue | |||||||||||
Lower cost of energy billed to customers | 5.0 | 284.9 | |||||||||
Lower tracker deferrals within operation and maintenance, depreciation and tax | 12.8 | 33.2 | |||||||||
| Total change in operating expense | $ | (38.1) | $ | 215.2 | |||||||
Electric Supply and Generation Transition
NIPSCO continues to execute on an electric generation transition consistent with the 2018 Plan and 2021 Plan, which outlines the path to retire the remaining two coal units at R.M. Schahfer by the end of 2025 and the remaining coal-fired generation at Michigan City by the end of 2028, to be replaced by lower-cost, reliable and cleaner options.
NIPSCO continues to await EPA decision on an administrative approval associated with the operation of R.M. Schahfer’s remaining two coal units until 2025. In the event that the approval is not obtained, future operations could be impacted. We cannot estimate the financial impact on us if this approval is not obtained. Refer to Item 1A. Risk Factors, "Operational Risks," of the 2023 Annual Report on Form 10-K for further detail.
The current replacement plan is aligned with the Preferred Energy Resource Plan outlined in the 2021 Plan and primarily includes renewable sources of energy, including wind, solar, battery storage, and flexible natural gas resources to be obtained through a combination of NIPSCO ownership and PPAs. NIPSCO has sold, and may in the future sell, renewable energy credits from its renewable generation to third parties to offset customer costs. NIPSCO has executed several PPAs to purchase 100% of the output from renewable generation facilities at a fixed price per MWh. Each facility supplying the energy will have an associated nameplate capacity, and payments under the PPAs will not begin until the associated generation facility is constructed by the owner/seller. NIPSCO has also executed several BTAs with developers to construct renewable generation facilities.
Since 2020, two wind PPA projects, two wind BTA projects and three solar BTA projects have been placed into service, totaling 1,665 MW of nameplate capacity plus additional battery energy storage system capacity at Cavalry. NIPSCO has executed commercial agreements for each of the seven remaining identified projects. Dunns Bridge II, Fairbanks, Gibson, GreenRiver, Appleseed, Carpenter and Templeton have received IURC approval. In January 2024, the IURC approved increases to the project costs as well as the full ownership of Cavalry and Dunns Bridge II. In August 2024, the IURC approved full ownership of Gibson and Fairbanks as well as increases to the cost of the Fairbanks project. NIPSCO has also contracted with a developer to convert the previously approved Templeton PPA to a BTA and has provided a notice of intent to file with the IURC. In October 2024 the IURC approved the certificate of public convenience and necessity for NIPSCO's planned gas peaking facility to be located at the R.M. Schahfer Generating Station. See "Executive Summary - Energy Transition" in this Management's Discussion for additional information. We expect the majority of our remaining BTA and PPA projects to be placed in service between 2025 and 2027.
51
ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (continued)
NiSource Inc.
NIPSCO Operations
Remaining Renewables Projects | Transaction Type | Technology | Nameplate Capacity (MW) | Storage Capacity (MW) | ||||||||||
Dunns Bridge II | BTA | Solar & Storage | 435 | 56.25 | ||||||||||
Fairbanks | BTA | Solar | 250 | — | ||||||||||
Gibson | BTA | Solar | 200 | — | ||||||||||
Templeton (1) | BTA | Wind | 200 | — | ||||||||||
| Green River | 20 year PPA | Solar | 200 | — | ||||||||||
| Appleseed | 20 year PPA | Solar | 200 | — | ||||||||||
| Carpenter | 20 year PPA | Wind | 200 | — | ||||||||||
(1) Pending regulatory approval.
52
ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (continued)
NiSource Inc.
Liquidity and Capital Resources
We continually evaluate the availability of adequate financing to fund our ongoing business operations, working capital and core safety and infrastructure investment programs. Our financing is sourced through cash flow from operations and the issuance of debt and/or equity. External debt financing is provided primarily through the issuance of long-term debt, accounts receivable securitization programs and our $1.85 billion commercial paper program, which is backstopped by our committed revolving credit facility with a total availability from third-party lenders of $1.85 billion. Sources of financing activities for the current year are as follows:
•On December 31, 2023, we consummated the NIPSCO Minority Interest Transaction in exchange for a capital contribution of $2.16 billion in cash.
•On January 3, 2024, we applied the proceeds from the NIPSCO Minority Interest Transaction and repaid in full our $1.0 billion term credit agreement and our $650.0 million term credit agreement.
•On February 22, 2024, we entered into an ATM equity program that provides an opportunity to issue and sell shares of our common stock up to an aggregate issuance of $900.0 million through December 31, 2025. As of September 30, 2024, the ATM program (including the impact of open forward sale agreements) had approximately $297.7 million of equity available for issuance.
•On March 14, 2024, we completed the issuance and sale of $650.0 million of 5.350% senior unsecured notes maturing in 2034, which resulted in approximately $642.6 million of net proceeds after discount and debt issuance costs.
•On March 15, 2024, we redeemed all 20,000 outstanding shares of Series B Preferred Stock for a redemption price of $25,000 per share and all 20,000 outstanding shares of Series B-1 Preferred Stock for a redemption price of $0.01 per share or $500.0 million in total.
•On May 16, 2024, we completed the issuance and sale of $500.0 million of 6.950%fixed-to-fixed reset rate junior subordinated notes maturing in 2054, which resulted in approximately $493.4 million million of net proceeds after debt issuance costs.
•On June 24, 2024, we completed the issuance and sale of $600.0 million of 5.200% senior unsecured notes maturing in 2029, which resulted in approximately $593.7 million of net proceeds after discount and debt issuance costs.
•On September 9, 2024, we completed the issuance and sale of $500.0 million of 6.375% fixed-to-fixed reset rate junior subordinated notes maturing in 2055, which resulted in approximately $493.6 million of net proceeds after debt issuance costs.
We believe these sources provide adequate capital to fund our operating activities and capital expenditures in 2024 and beyond. See Note 4, "Noncontrolling Interests," Note 6, "Equity," Note 7, "Short-Term Borrowings," and Note 8, "Long-Term Debt," in the Notes to the Condensed Consolidated Financial Statements (unaudited) for more information on our financing activities.
The following table summarizes our cash flow activities:
Nine Months Ended September 30, | |||||||||||||||||
| (in millions) | 2024 | 2023 | Change in 2024 vs 2023 | ||||||||||||||
| Cash from (used for): | |||||||||||||||||
| Operating Activities | $ | 1,241.7 | $ | 1,535.9 | $ | (294.2) | |||||||||||
| Investing Activities | (2,414.5) | (2,503.3) | 88.8 | ||||||||||||||
| Financing Activities | (949.5) | 998.6 | (1,948.1) | ||||||||||||||
Operating Activities
The decrease in cash from operating activities was primarily driven by year over year change in accounts receivable collections, inventory and exchange gas receivables due to the impact of lower gas prices, partially offset by higher accounts payables and net income.
53
ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (continued)
NiSource Inc.
Investing Activities
Year over year decrease in investing activities was primarily comprised of lower capital expenditures spending.
We remain on track to make capital investments totaling $3.3 billion to $3.5 billion during the 2024 period. We also expect to invest approximately $19.3 billion during the 2025-2029 period, including capital investments to support our generation transition strategy. These forecasted capital investments are subject to continuing review and adjustment. Actual capital expenditures may vary from these estimates.
Regulatory Capital Programs. We are in the process of upgrading and modernizing our electric system to enhance safety and reliability by addressing aged infrastructure and deploying advanced grid technologies. We are also upgrading and modernizing our gas infrastructure to enhance safety and reliability by reducing leaks. An ancillary benefit of these programs is the reduction of GHG emissions. In 2024, we continue to move forward on core infrastructure and environmental investment programs supported by complementary regulatory and customer initiatives across all six states of our operating area.
The following table describes the most recent vintage of our regulatory programs to recover infrastructure replacement and other federally mandated compliance investments:
| (in millions) | |||||||||||||||||
| Company | Program | Capital Investment | Investment Period | Filing Date | Costs Covered(1) | ||||||||||||
Approved | |||||||||||||||||
Columbia of Pennsylvania | DSIC - Q4 2024 | $ | 180.1 | 2/24-8/24 | 9/20/2024 | Eligible project costs including piping, couplings, gas service lines, excess flow valves, risers, meter bars, meters, and other related capitalized investments to improve the distribution system. | |||||||||||
| Columbia of Ohio | IRP - 2024 | $ | 753.5 | 4/21-12/23 | 2/26/2024 | Replacement of hazardous service lines, cast iron, wrought iron, uncoated steel, and bare steel pipe. | |||||||||||
Columbia of Ohio | PHMSA IRP - 2024 | $ | 14.6 | 1/23-12/23 | 2/28/2024 | Investments necessary to comply with the PHMSA Mega Rule. | |||||||||||
| Columbia of Ohio | CEP - 2024 | $ | 763.3 | 4/21-12/23 | 2/26/2024 | Assets not included in the IRP or PHMSA IRP. | |||||||||||
NIPSCO - Gas | FMCA - 2 | $ | 11.1 | 1/23-9/23 | 11/29/2023 | Project costs to comply with federal mandates. | |||||||||||
Columbia of Virginia | SAVE - 2024 | $ | 166.5 | 10/22-12/24 | 8/15/2023 | Replacement projects that (1) enhance system safety or reliability, or (2) reduce, or potentially reduce, greenhouse gas emissions. Includes costs associated with Advanced Leak Detection and Repair. | |||||||||||
Columbia of Kentucky | SMRP - 2024 | $ | 81.9 | 1/23-12/24 | 10/13/2023 | Replacement of mains and inclusion of system safety investments. | |||||||||||
NIPSCO - Electric | TDSIC - 5 | $ | 346.9 | 7/22-3/24 | 5/28/2024 | New or replacement projects undertaken for the purpose of safety, reliability, system modernization or economic development. | |||||||||||
NIPSCO - Gas | TDSIC - 8 | $ | 8.3 | 1/23-2/24 | 4/30/2024 | New or replacement projects undertaken for the purpose of safety, reliability, system modernization or economic development. | |||||||||||
Pending Commission Approval | |||||||||||||||||
Columbia of Kentucky | SMRP - 2025 | $ | 128.5 | 1/23-12/25 | 10/15/2024 | Replacement of mains and inclusion of system safety investments. | |||||||||||
Columbia of Virginia | SAVE - 2025 | $ | 89.0 | 10/24-12/25 | 8/15/2024 | Replacement projects that (1) enhance system safety or reliability, or (2) reduce, or potentially reduce, greenhouse gas emissions. Includes costs associated with Advanced Leak Detection and Repair. | |||||||||||
NIPSCO - Gas | FMCA - 3 | $ | 27.0 | 1/23-6/24 | 8/27/2024 | Project costs to comply with federal mandates. | |||||||||||
Columbia of Maryland | STRIDE - 2025 | $ | 14.8 | 1/25-12/25 | 7/30/2024 | Pipeline upgrades designed to improve public safety or infrastructure reliability. | |||||||||||
(1)Programs do not include any costs already included in base rates.
Financing Activities
Common Stock and Preferred Stock. Refer to Note 6, "Equity," in the Notes to the Condensed Consolidated Financial Statements (unaudited) for information on common and preferred stock.
54
ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (continued)
NiSource Inc.
Long-Term Debt. Refer to Note 8, "Long-Term Debt," in the Notes to the Condensed Consolidated Financial Statements (unaudited) for information on long-term debt activity.
Short-Term Debt. Refer to Note 7, "Short-Term Borrowings," in the Notes to the Condensed Consolidated Financial Statements (unaudited) for information on short-term debt activity.
Noncontrolling Interest. We received $2.16 billion upon closing the NIPSCO Minority Interest Transaction. Proceeds from the closing of the NIPSCO Minority Interest Transaction were used to repay short-term debt, including our credit agreements. Under the terms of the Amended LLC Agreement, BIP is obligated to provide up to $250 million in additional capital contributions over a three-year period after the Closing. The obligation is backed by an Equity Commitment Letter from Blackstone. BIP may contribute additional capital above $250 million as necessary to maintain its percentage ownership interest. Refer to Note 4, "Noncontrolling Interests," in the Notes to the Condensed Consolidated Financial Statements (unaudited) for information on contributions and distributions from noncontrolling interests.
Sources of Liquidity
The following table displays our liquidity position as of September 30, 2024 and December 31, 2023:
| (in millions) | September 30, 2024 | December 31, 2023 | ||||||
| Current Liquidity | ||||||||
| Revolving Credit Facility | $ | 1,850.0 | $ | 1,850.0 | ||||
Accounts Receivable Programs(1) | 225.0 | 383.9 | ||||||
| Less: | ||||||||
| Commercial Paper | 257.0 | 1,061.0 | ||||||
| Accounts Receivable Programs Utilized | — | 337.6 | ||||||
| Letters of Credit Outstanding Under Credit Facility | 9.4 | 9.9 | ||||||
| Add: | ||||||||
| Cash and Cash Equivalents | 126.2 | 2,245.4 | ||||||
| Net Available Liquidity | $ | 1,934.8 | $ | 3,070.8 | ||||
(1)Represents the lesser of the seasonal limit or maximum borrowings supportable by the underlying receivables.
Debt Covenants. We are subject to a financial covenant under our revolving credit facility, which requires us to maintain a debt to capitalization ratio that does not exceed 70.0%. As of September 30, 2024, the ratio was 52.7%.
Credit Ratings. The credit rating agencies periodically review our ratings, taking into account factors such as our capital structure and earnings profile. The following table includes our and NIPSCO's credit ratings and ratings outlook as of September 30, 2024. There were no changes to the below credit ratings or outlooks since February 2020.
A credit rating is not a recommendation to buy, sell, or hold securities, and may be subject to revision or withdrawal at any time by the assigning rating organization.
| S&P | Moody's | Fitch | ||||||||||||||||||
| Rating | Outlook | Rating | Outlook | Rating | Outlook | |||||||||||||||
| NiSource | BBB+ | Stable | Baa2 | Stable | BBB | Stable | ||||||||||||||
| NIPSCO | BBB+ | Stable | Baa1 | Stable | BBB | Stable | ||||||||||||||
| Commercial Paper | A-2 | Stable | P-2 | Stable | F2 | Stable | ||||||||||||||
55
ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (continued)
NiSource Inc.
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 September 30, 2024, the collateral requirement that would be required in the event of a downgrade below the ratings trigger levels would amount to approximately $112.4 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 770,000,000 shares, $0.01 par value, of which 750,000,000 are common stock and 20,000,000 are preferred stock. As of September 30, 2024, 466,707,452 shares of common stock were outstanding.
Contractual Obligations. A summary of contractual obligations is included in the Company's Annual Report on Form 10-K for the year ended December 31, 2023. Except for our 2024 debt issuances, there were no additional material changes from year-end during the nine months ended September 30, 2024. Refer to Note 8, "Long-Term Debt," in the Notes to the Condensed Consolidated Financial Statements (unaudited) for additional information regarding the debt issuances.
Guarantees, Indemnities and Other Off Balance Sheet Arrangements. 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. Refer to Note 15, "Other Commitments and Contingencies," in the Notes to the Condensed Consolidated Financial Statements (unaudited) for additional information about such arrangements.
56
ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (continued)
NiSource Inc.
Regulatory, Environmental and Safety 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 costs that are subject to approved regulatory tracker mechanisms generally lead to increased regulatory assets, which ultimately result in a corresponding increases in operating revenues and expenses and, therefore, have essentially no impact on total operating income results. Certain approved regulatory tracker mechanisms allow for abbreviated regulatory proceedings in order for the operating companies to quickly implement revised rates and recover associated costs.
A portion of the Columbia Operations and NIPSCO Operations revenue is related to the recovery of gas costs, the review and recovery of which occurs through standard regulatory proceedings. All states in our operating area require periodic review of actual gas procurement activity to determine prudence and to confirm the recovery of prudently incurred energy commodity costs supplied to customers.
We recognize that energy efficiency reduces emissions, conserves natural resources and saves our customers money. Our gas distribution companies offer programs such as energy efficiency upgrades, home checkups and weatherization services. The increased efficiency of natural gas appliances and improvements in home building codes and standards contributes to a long-term trend of declining average use per customer. While we are looking to expand offerings so the energy efficiency programs can benefit as many customers as possible, our Columbia Operations and NIPSCO Operations have pursued changes in rate design to more effectively match recoveries with costs incurred. Columbia of Ohio has adopted a straight fixed variable rate design for residential customers that closely links the recovery of fixed costs with fixed charges. Columbia of Maryland, Columbia of Virginia and NIPSCO Gas have regulatory approval for weather and revenue normalization adjustments for certain customer classes, which adjust monthly revenues that exceed or fall short of approved levels. Columbia of Pennsylvania continues to operate its pilot residential weather normalization adjustment and also has a fixed customer charge. This weather normalization adjustment only adjusts revenues when actual weather compared to normal varies by more than 3% during the winter heating season. Columbia of Kentucky incorporates a weather normalization adjustment for certain customer classes and also has a fixed customer charge.
A portion of the NIPSCO Operations revenue is related to the recovery of fuel costs to generate power and the fuel costs related to purchased power. These costs are recovered through a FAC, which is updated quarterly to reflect actual costs incurred to supply electricity to customers.
While increased efficiency of electric appliances and improvements in home building codes and standards has impacted the average use per electric customer in recent years, NIPSCO Operations expects future growth in residential and commercial customer usage as a result of increasing electric applications, such as electric vehicles becoming more prevalent. These ongoing changes in use of electricity will likely lead to development of innovative rate designs, and NIPSCO Operations will continue efforts to design rates that increase the certainty of recovery of fixed costs.
57
ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (continued)
NiSource Inc.
Regulatory, Environmental and Safety Matters
Rate Case Actions
The following table describes current rate case actions as applicable in each of our jurisdictions net of tracker impacts:
| (in millions) | |||||||||||||||||
| Company | Approved ROE | Requested Incremental Revenue | Approved Incremental Revenue | Filing Date | Rates Effective | ||||||||||||
| Approved Rate Cases | |||||||||||||||||
Columbia of Pennsylvania(1) | None specified | $ | 82.2 | $ | 44.5 | March 18, 2022 | December 2022 | ||||||||||
Columbia of Maryland(1) | None specified | $ | 6.5 | $ | 3.9 | May 12, 2023 | December 2023 | ||||||||||
Columbia of Kentucky(2) | 9.35 | % | $ | 26.7 | $ | 18.3 | May 28, 2021 | January 2022 | |||||||||
Columbia of Virginia(3) | None specified | $ | 40.5 | $ | 25.8 | April 29, 2022 | October 2022 | ||||||||||
| Columbia of Ohio | 9.60 | % | $ | 221.4 | $ | 68.3 | June 30, 2021 | March 2023 | |||||||||
NIPSCO - Gas(4) | 9.75 | % | $ | 161.9 | $ | 120.9 | October 25, 2023 | September 2024 | |||||||||
NIPSCO - Electric(5) | 9.80 | % | $ | 291.8 | $ | 261.9 | September 19, 2022 | August 2023 | |||||||||
| Pending Rate Cases | |||||||||||||||||
Columbia of Kentucky(6) | In process | $ | 23.8 | In process | May 16, 2024 | January 2025 | |||||||||||
Columbia of Pennsylvania(7) | In process | $ | 124.1 | In process | March 15, 2024 | December 2024 | |||||||||||
NIPSCO - Electric(8) | In process | $ | 368.7 | In process | September 12, 2024 | September 2025 | |||||||||||
Columbia of Virginia(9) | In process | $ | 37.2 | In process | April 29, 2024 | October 2024 | |||||||||||
Columbia of Maryland | In process | $ | 8.7 | In process | September 24, 2024 | April 2025 | |||||||||||
(1)No approved ROE is identified for this matter since the approved revenue increase is the result of a black box settlement under which parties agree upon the amount of increase.
(2)The approved ROE for natural gas capital riders (e.g., SMRP) is 9.275%.
(3)Columbia of Virginia's rate case resulted in a black box settlement, representing a settlement to a specific revenue increase but not a specified ROE. The settlement provides use of a 9.70% ROE for future SAVE and filings.
(4)New rates will be implemented in 2 steps, with implementation of Step 1 rates effective in August 2024 and Step 2 rates to be effective no later than March 2025.
(5)New rates were implemented in 2 steps, with implementation of Step 1 rates effective in August 2023 and Step 2 rates effective in March 2024.
(6)Columbia of Kentucky, and the intervening parties filed a Joint Stipulation, Settlement Agreement and Recommendation on October 14, 2024, for an annual revenue increase of $14.3 million.
(7)The parties to Columbia of Pennsylvania’s rate case filed a Joint Petition for Partial Settlement on August 22, 2024, for an annual revenue increase of $74.0 million. On October 1, 2024, the Administrative Law Judge issued their recommended decision to approve the Partial Settlement without modification.
(8)New rates proposed to be implemented in 2 steps, with implementation of Step 1 rates effective no later than September 2025 and Step 2 rates to be effective no later than March 2026.
(9)Rates to be effective on an interim basis and subject to refund.
PHMSA Legislation and Regulations
We are committed to reducing the environmental impact of our business and promoting sustained environmental stewardship. We seek proactive opportunities for improved environmental performance and are committed to complying with environmental laws and regulations. To fulfill our vision of being a trusted energy provider, we follow safety practices recommended by leading industry organizations. These practices help us identify and address potential risks, resulting in improvements to our operational and environmental safety.
Under the Protecting Our Infrastructure of Pipelines and Enhancing Safety (PIPES) Act of 2020, PHMSA has revised, and continues to revise, the pipeline safety regulations to require operators to update, as needed, their existing distribution integrity management plans, emergency response plans, and operation and maintenance plans. PHMSA has also adopted new requirements for managing records and updating, as necessary, existing district regulator stations to eliminate common modes of failure that can lead to over-pressurization.
In May 2023, PHMSA proposed numerous regulatory revisions under the PIPES Act of 2020 to minimize methane emissions and improve public safety. Under these proposed revisions, our subsidiaries would be required to detect and repair an increased number of gas leaks, reduce the time to repair leaks, increase leak survey frequency, and expand our existing advanced leak detection program. We continue to evaluate the proposed rule for additional impacts on our business.
In September 2023, PHMSA proposed additional regulatory revisions under the PIPES Act of 2020 to enhance distribution system safety through equipment and procedural expectations. Operators will be required to incorporate additional protections for low pressure distribution systems that prevent over-pressurization, amend construction procedures designed to minimize the
58
ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (continued)
NiSource Inc.
Regulatory, Environmental and Safety Matters
risk of incidents caused by system over-pressurization, and update distribution integrity management programs to cover and prepare for over-pressurization incidents.
On November 30, 2023, the House Transportation & Infrastructure Committee introduced new pipeline safety reauthorization legislation known as the PIPES Act of 2023 to reauthorize PHMSA’s safety programs for the next four years. The proposed legislation includes several priorities for our company, including excavation damage prevention grants to improve states’ damage prevention programs, a PHMSA study on blending hydrogen in distribution pipelines, new criminal penalties for intentionally damaging pipeline facilities, and creation of a Voluntary Information Sharing System to allow for industry participants to share learnings and best practices in a protected manner across the pipeline industry.
Climate Change Issues
Physical Climate Risks. Increased frequency of severe and extreme weather events associated with climate change could materially impact our facilities, energy sales, and results of operations. We are unable to predict these events. However, we perform ongoing assessments of physical risk, including physical climate risk, to our business. More extreme and volatile temperatures, increased storm intensity and flooding, and more volatile precipitation leading to changes in lake and river levels are among the weather events that are most likely to impact our business. Efforts to mitigate these physical risks continue to be implemented on an ongoing basis.
Transition Climate Risks. We actively engage with and monitor the impact that proposed legislative and regulatory programs related to GHG emissions would have on our business, at both the federal and state levels.
Regarding federal policies, we continue to monitor the implementation of any final and proposed climate change-related legislation and regulations, including the Infrastructure Investment and Jobs Act ("IIJA"), IRA, EPA's final methane regulations for the oil and natural gas industry, and EPA's proposed Waste Emissions Charge for Petroleum and Natural Gas Systems. We have identified potential opportunities associated with the IIJA and the IRA and are evaluating how they may align with our strategy going forward. The energy-related provisions of the IIJA include new federal funding for power grid infrastructure and resiliency investments, new and existing energy efficiency and weatherization programs, electric vehicle infrastructure for public chargers and additional LIHEAP funding. The IRA contains climate and energy provisions, including funding to decarbonize the electric sector.
The United States is a party to the Paris Agreement, an international treaty through which parties set nationally determined contributions to reduce GHG emissions, build resilience, and adapt to the impacts of climate change. The Biden Administration has set a target for the United States to achieve a 50%-52% GHG reduction from 2005 levels by 2030, which supports the President's goals to create a carbon-free power sector by 2035 and net zero emissions economy no later than 2050. There are many potential pathways to reach these goals.
The DOE has selected two hydrogen hubs in our territories as recipients of funding designated in the IIJA to support the development of regional clean hydrogen hubs. The two hubs are the Midwest Alliance for Clean Hydrogen Hub (MachH2), with potential projects across Illinois, Indiana, Kentucky, Michigan, Missouri, and Wisconsin; and the Appalachian Regional Clean Hydrogen Hub (ARCH2), with potential investments across West Virginia, Ohio, Kentucky, and Pennsylvania. Work is underway to determine what roles our companies may have with these hydrogen hubs.
In May 2024, the EPA published final greenhouse gas standards and guidelines for fossil fuel-fired power plants. The rules are not expected to impact NIPSCO’s existing electric generation, but, depending on the outcome of ongoing litigation, may impose certain operational limitations on other existing and new electric generation. We are assessing the potential impacts of these rules through the current 2024 NIPSCO Integrated Resource Planning process.
59
ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (continued)
NiSource Inc.
Regulatory, Environmental and Safety Matters
We also continue to monitor the implementation of any final and proposed state policy. The Virginia Energy Innovation Act, enacted into law in April 2022, and effective July 1, 2022, allows natural gas utilities to supply alternative forms of gas that meet certain standards and reduce emissions intensity. The Act also provides that the costs of enhanced leak detection and repair may be added to a utility’s plan to identify proposed eligible infrastructure replacement projects and related cost recovery mechanisms, known as the SAVE Plan. Furthermore, under the Act, utilities can recover eligible biogas supply infrastructure costs on an ongoing basis. The provisions of these laws may provide opportunities for Columbia of Virginia as it participates in the transition to a lower carbon future.
The Climate Solutions Now Act of 2022 requires Maryland to reduce GHG emissions by 60% by 2031 (from 2006 levels), and it requires the state to reach net zero emissions by 2045. The Maryland Department of the Environment ("MDE") adopted a plan to achieve its 2031 goal and is required to adopt a plan for its 2045 net zero goal by 2030. In June 2024, Governor Moore signed an executive order to advance Maryland’s Pollution Reduction Plan, which directs the MDE to propose a zero-emission heating equipment standard regulation and a clean heat standard regulation. The Act also enacts a state policy to move to broader electrification of both existing buildings and new construction, and requires the Public Service Commission ("PSC") to complete a study assessing the capacity of gas and electric distribution systems to successfully serve customers under a transition to a highly electrified building sector. The PSC released their report on December 29, 2023, and concluded that high levels of electrification can be handled by Maryland's electric systems through 2031. On September 6, 2024, the Maryland Department of the Environment issued updated proposed Building Energy Performance Standards (BEPS), which would require net zero direct greenhouse gas emissions from large buildings by 2040 with interim targets, or payments of an alternative compliance fee. Columbia of Maryland is advocating for compliance pathways that use RNG, hydrogen, and emissions offsets. Separately, the PSC has also initiated a proceeding related to Near-Term, Priority Actions and Comprehensive, Long-Term Planning for Maryland's Gas Companies. Columbia of Maryland will continue to monitor these matters, but we cannot predict their final impact on our business at this time.
NIPSCO Gas, Columbia of Maryland, Columbia of Pennsylvania, Columbia of Virginia and Columbia of Kentucky have each filed petitions to implement the Green Path Rider, which is a voluntary rider allowing customers to opt in and offset either 50% or 100% of their natural gas related emissions. To reduce the emissions, the utilities will purchase RNG attributes and carbon offsets to match the usage for customers opting into the program. After reaching settlement with other parties in September 2022, NIPSCO agreed to add a third tier to offset 25% of customer usage. The program was approved by the IURC at NIPSCO in November 2022 with a January 2023 start date. Columbia of Virginia received a final order in May 2023, approving the Green Path Rider and began enrolling customers in September 2023. The petitions filed by Columbia of Maryland, Columbia of Pennsylvania, and Columbia of Kentucky were rejected by the state commissions in 2023. Additionally, NIPSCO Electric has a voluntary Green Power Rider program in place that allows customers to designate a portion or all their monthly electric usage to come from power generated by renewable energy sources.
Net Zero Goal. In November 2022, we announced a goal of net zero greenhouse gas emissions by 2040 covering both Scope 1 and Scope 2 GHG emissions ("Net Zero Goal"). Our Net Zero Goal builds on greenhouse gas emission reductions achieved to-date. We plan to achieve our Net Zero Goal primarily through continuation and enhancement of existing programs, such as retiring and replacing coal-fired electric generation with low- or zero-emission electric generation, ongoing pipe replacement and modernization programs, and deployment of advanced leak-detection technologies. In addition, we plan to advance other low- and zero-emission energy resources and technologies, which may include hydrogen, renewable natural gas, long-duration storage, and/or deployment of carbon capture and utilization technologies, if and when these become technologically and economically feasible. Carbon offsets and renewable energy credits may also be used to support achievement of our Net Zero Goal. As of the end of 2023, we had reduced Scope 1 GHG emissions by approximately 72% from 2005 levels.
Our greenhouse gas emissions projections, including achieving a Net Zero Goal, are subject to various assumptions that involve risks and uncertainties, and did not include any assumptions related to data center development and associated load growth. We remain committed to our Net Zero Goal, however, certain of our interim goals may evolve as we assess and respond to business opportunities such as data centers. Achievement of our Net Zero Goal by 2040 will require supportive regulatory and legislative policies, favorable stakeholder environments, advancement of technologies that are not currently economical to deploy, and execution of our business plan, otherwise our actual results or ability to achieve our Net Zero Goal, including by 2040, may differ materially.
60
ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (continued)
NiSource Inc.
Market Risk Disclosures
Risk is an inherent part of our businesses. The extent to which we properly and effectively identify, assess, monitor and manage each of the various types of risk involved in our businesses is critical to our profitability. We seek to identify, assess, monitor and manage, in accordance with defined policies and procedures, the following principal market risks that are involved in our businesses: commodity price risk, interest rate risk and credit risk. We manage risk through a multi-faceted process with oversight by the Risk Management Committee that requires constant communication, judgment and knowledge of specialized products and markets. Our senior management takes an active role in the risk management process and has developed policies and procedures that require specific administrative and business functions to assist in the identification, assessment and control of various risks. These may include, but are not limited to market, operational, financial, compliance and strategic risk types. In recognition of the increasingly varied and complex nature of the energy business, our risk management process, policies and procedures continue to evolve and are subject to ongoing review and modification.
Commodity Price Risk
Our gas and electric subsidiaries have commodity price risk primarily related to the purchases of 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 and does not bear signification exposure to earnings risk, since our current regulatory mechanisms allow recovery of prudently incurred purchased power, fuel and gas costs through the rate-making process, including gains or losses on these derivative instruments. These changes are included in the GCA and FAC regulatory rate-recovery mechanisms. If these mechanisms were to be adjusted or eliminated, these subsidiaries may begin providing services without the benefit of the traditional rate-making process and may be more exposed to commodity price risk. For additional information, see "Results and Discussion of Segment Operations" in this Management's Discussion.
Our subsidiaries are required to make cash margin deposits with their brokers to cover actual and potential losses in the value of outstanding exchange traded derivative contracts. The amount of these deposits, some of which are reflected in our restricted cash balance, may fluctuate significantly during periods of high volatility in the energy commodity markets.
Refer to Note 11, "Risk Management Activities," in the Notes to the Condensed Consolidated Financial Statements (unaudited) for further information on our commodity price risk assets and liabilities as of September 30, 2024 and December 31, 2023.
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, and accounts receivable programs, which have interest rates that are indexed to short-term market interest rates. Based upon average borrowings and debt obligations subject to fluctuations in short-term market interest rates, an increase (or decrease) in short-term interest rates of 100 basis points (1%) would have increased (or decreased) interest expense by $1.7 million and $6.9 million for the three and nine months ended September 30, 2024 and $4.8 million and $12.4 million for the three and nine months ended September 30, 2023, 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 long-term debt issuances. From time to time we may enter into forward interest rate instruments to lock in long term interest costs and/ or rates.
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 Management Policy which establishes guidelines for documenting management approval levels for credit limits, evaluating 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 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.
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ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (continued)
NiSource Inc.
Other Information
Critical Accounting Estimates
A summary of our critical accounting estimates is included in the Company's Annual Report on Form 10-K for the year ended December 31, 2023. There were no material changes made as of September 30, 2024.
Recently Issued Accounting Pronouncements
Refer to Note 2, "Recent Accounting Pronouncements," in the Notes to the Condensed Consolidated Financial Statements (unaudited) for additional information about recently issued and adopted accounting pronouncements.
62
NiSource Inc.
ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK
Quantitative and qualitative disclosures about market risk are reported in Item 2, "Management's Discussion and Analysis of Financial Condition and Results of Operations - Market Risk Disclosures."
ITEM 4. CONTROLS AND PROCEDURES
Evaluation of Disclosure Controls and Procedures
Our chief executive officer and our chief financial officer are responsible for evaluating the effectiveness of our disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)). Our disclosure controls and procedures are designed to provide reasonable assurance that the information required to be disclosed by us in reports that we file or submit under the Exchange Act is accumulated and communicated to our management, including our chief executive officer and chief financial officer, as appropriate, to allow timely decisions regarding required disclosure and is recorded, processed, summarized and reported within the time periods specified in the rules and forms of the SEC. Based upon that evaluation, our chief executive officer and chief financial officer concluded that, as of the end of the period covered by this report, our disclosure controls and procedures were effective to provide reasonable assurance that financial information was processed, recorded and reported accurately.
Changes in Internal Controls
There have been no changes in our internal control over financial reporting during the most recently completed quarter covered by this report that has materially affected, or is reasonably likely to materially affect, our internal control over financial reporting.
63
NiSource Inc.
PART II
ITEM 1. LEGAL PROCEEDINGS
For a description of our legal proceedings, see Note 15, "Other Commitments and Contingencies - B. Legal Proceedings," in the Notes to the Condensed Consolidated Financial Statements (unaudited).
ITEM 1A. RISK FACTORS
Please refer to the risk factors set forth in Part I, Item 1A of the Annual Report on Form 10-K for the year ended December 31, 2023. There have been no material changes to such risk factors other than as set forth below.
We may not be able to execute our business plan or growth strategy, including utility infrastructure investments, or business opportunities, such as data center development and related generation sources and transmission capabilities to meet potential load growth.
Operational, financial or regulatory conditions may result in our inability to execute our business plan or growth strategy, including investments related to natural gas pipeline modernization and our renewable energy projects, and the build-transfer execution goals within our business plan. Additionally, operational, financial or regulatory conditions may result in our inability to manage the development and implementation connected to the complex business opportunity associated with growing interest in data centers from customers and potential customers.
Our enterprise-wide transformation roadmap initiatives are designed to identify long-term sustainable capability enhancements, cost optimization improvements, technology investments and work process optimization, has increased the volume and pace of change and may not be effective as it continues. Our customer and regulatory initiatives may not achieve planned results. Utility infrastructure investments may not materialize, may cease to be achievable or economically viable and may not be successfully completed. Furthermore, we are evaluating the potential for data center development in our service territory, including ways to effectively manage the potential power demand, generation sources, and transmission capabilities to meet potential load growth from any data center customer, while at the same time focusing on our environmental goals. We expect that management of load growth would require new generation and transmission capabilities. Natural gas may cease to be viewed as an economically and environmentally attractive fuel. Certain environmental activist groups, investors and governmental entities continue to oppose natural gas delivery and infrastructure investments because of perceived environmental impacts associated with the natural gas supply chain and end use. Energy conservation, energy efficiency, distributed generation, energy storage, policies favoring electric heat over gas heat and other factors may reduce demand for natural gas and electricity. In addition, we consider acquisitions or dispositions of assets or businesses, JVs, and mergers from time to time as we execute on our business plan and growth strategy. As data center opportunities evolve and develop, we may also enter into arrangements and agreements with customers and potential customers that require us to invest capital related to the data center development and related generation sources and transmission capabilities before we receive any potential return. Any of these circumstances could adversely affect our business, results of operations and growth prospects. Even if our business plan, growth strategy, and/or business opportunities are executed, there is still risk of, among other things, human error in maintenance, installation or operations, shortages or delays in obtaining equipment, including as a result of transportation delays and availability, labor availability and performance below expected levels (in addition to the other risks discussed in this section). We are currently experiencing, and expect to continue to experience, supply chain challenges, including labor availability issues, impacting our ability to obtain materials for our gas and electric projects, as well as our ability to ensure timely completion.
ITEM 2. UNREGISTERED SALES OF EQUITY SECURITIES AND USE OF PROCEEDS
None.
ITEM 3. DEFAULTS UPON SENIOR SECURITIES
None.
ITEM 4. MINE SAFETY DISCLOSURES
Not applicable.
ITEM 5. OTHER INFORMATION
64
Director and Officer Trading Arrangements
During the three months ended September 30, 2024, no director or Section 16 officer of the Company adopted, terminated or modified a ‘Rule 10b5-1 trading arrangement’ or ‘non-Rule 10b5-1 trading arrangement,’ as each term is defined in Item 408(a) of Regulation S-K.
65
ITEM 6. EXHIBITS
NiSource Inc.
| (3.1) | Articles of Incorporation of NiSource Inc., as amended and restated through October 21, 2024 (incorporated by reference to Exhibit 3.3 to the NiSource Inc. Form 8-K filed on October 22, 2024). | ||||
| (3.2) | Bylaws of NiSource Inc., as amended and restated through October 21, 2024 (incorporated by reference to Exhibit 3.4 to the NiSource Inc. Form 8-K filed October 22, 2024). | ||||
| (4.1) | Form of 6.375% Fixed-to-Fixed Reset Rate Junior Subordinated Notes due 2055 (incorporated by reference to Exhibit 4.1 to the NiSource Inc. Form 8-K filed on September 09, 2024). | ||||
| (4.2) | Second Supplemental Indenture, dated as of September 09, 2024, between NiSource Inc. and The Bank of New York Mellon, as trustee (incorporated by reference to Exhibit 4.2 to the NiSource Form 8-K filed on September 09, 2024). | ||||
| (10.1) | |||||
| (31.1) | |||||
| (31.2) | |||||
| (32.1) | |||||
| (32.2) | |||||
| (101.INS) | Inline XBRL Instance Document - the instance document does not appear in the Interactive Data File because its XBRL tags are embedded within the Inline XBRL document. | ||||
| (101.SCH) | Inline XBRL Schema Document | ||||
| (101.CAL) | Inline XBRL Calculation Linkbase Document | ||||
| (101.LAB) | Inline XBRL Labels Linkbase Document | ||||
| (101.PRE) | Inline XBRL Presentation Linkbase Document | ||||
| (101.DEF) | Inline XBRL Definition Linkbase Document | ||||
| (104) | Cover page Interactive Data File (formatted as inline XBRL, and contained in Exhibit 101.) | ||||
* | Exhibit filed herewith. | ||||
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SIGNATURE
NiSource Inc.
Pursuant to the requirements of the Securities Exchange Act of 1934, the Registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized.
| NiSource Inc. | ||||||||||||||
| (Registrant) | ||||||||||||||
| Date: | October 30, 2024 | By: | /s/ Gunnar J. Gode | |||||||||||
| Gunnar J. Gode | ||||||||||||||
| Vice President, Chief Accounting Officer (Principal Accounting Officer) | ||||||||||||||
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