PART I - FINANCIAL INFORMATION
ITEM 1. CONSOLIDATED FINANCIAL STATEMENTS
| ONE Gas, Inc. |
| CONSOLIDATED STATEMENTS OF INCOME |
| Three Months Ended |
| March 31, |
| (Unaudited) | 2023 | 2022 |
| (Thousands of dollars, except per share amounts) |
| Total revenues | $ | 1,032,143 | $ | 971,459 |
| Cost of natural gas | 665,799 | 639,946 |
| Operating expenses |
| Operations and maintenance | 126,683 | 115,095 |
| Depreciation and amortization | 71,264 | 57,137 |
| General taxes | 19,166 | 18,524 |
| Total operating expenses | 217,113 | 190,756 |
| Operating income | 149,231 | 140,757 |
| Other income (expense), net | 2,581 | ( 4,145 ) |
| Interest expense, net | ( 30,115 ) | ( 15,595 ) |
| Income before income taxes | 121,697 | 121,017 |
| Income taxes | ( 19,076 ) | ( 22,083 ) |
| Net income | $ | 102,621 | $ | 98,934 |
| Earnings per share |
| Basic | $ | 1.85 | $ | 1.83 |
| Diluted | $ | 1.84 | $ | 1.83 |
| Average shares (thousands) |
| Basic | 55,538 | 53,922 |
| Diluted | 55,800 | 54,030 |
| Dividends declared per share of stock | $ | 0.65 | $ | 0.62 |

See accompanying Notes to Consolidated Financial Statements.
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| ONE Gas, Inc. |
| CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME |
| Three Months Ended |
| March 31, |
| (Unaudited) | 2023 | 2022 |
| (Thousands of dollars) |
| Net income | $ | 102,621 | $ | 98,934 |
| Other comprehensive income, net of tax |
| Change in pension and other postemployment benefit plan liability, net of tax of $ — and $( 19 ), respectively | — | 69 |
| Total other comprehensive income, net of tax | — | 69 |
| Comprehensive income | $ | 102,621 | $ | 99,003 |

See accompanying Notes to Consolidated Financial Statements.
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| ONE Gas, Inc. |
| CONSOLIDATED BALANCE SHEETS |
| March 31, | December 31, |
| (Unaudited) | 2023 | 2022 |
| Assets | (Thousands of dollars) |
| Property, plant and equipment |
| Property, plant and equipment | $ | 7,957,407 | $ | 7,834,557 |
| Accumulated depreciation and amortization | 2,226,565 | 2,205,717 |
| Net property, plant and equipment | 5,730,842 | 5,628,840 |
| Current assets |
| Cash and cash equivalents | 7,809 | 9,681 |
| Restricted cash and cash equivalents | 19,117 | 8,446 |
| Total cash, cash equivalents and restricted cash and cash equivalents | 26,926 | 18,127 |
| Accounts receivable, net | 493,573 | 553,834 |
| Materials and supplies | 73,033 | 70,873 |
| Natural gas in storage | 98,966 | 269,205 |
| Regulatory assets | 66,198 | 275,572 |
| Other current assets | 29,773 | 29,997 |
| Total current assets | 788,469 | 1,217,608 |
| Goodwill and other assets |
| Regulatory assets | 308,960 | 330,831 |
| Securitized intangible asset, net | 316,749 | 323,838 |
| Goodwill | 157,953 | 157,953 |
| Other assets | 117,279 | 117,326 |
| Total goodwill and other assets | 900,941 | 929,948 |
| Total assets | $ | 7,420,252 | $ | 7,776,396 |

See accompanying Notes to Consolidated Financial Statements.
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| ONE Gas, Inc. |
| CONSOLIDATED BALANCE SHEETS |
| (Continued) |
| March 31, | December 31, |
| (Unaudited) | 2023 | 2022 |
| Equity and Liabilities | (Thousands of dollars) |
| Equity and long-term debt |
| Common stock, $ 0.01 par value:authorized 250,000,000 shares; issued and outstanding 55,389,050 shares at March 31, 2023; issued and outstanding 55,349,954 shares at December 31, 2022 | $ | 553 | $ | 553 |
| Paid-in capital | 1,933,468 | 1,932,714 |
| Retained earnings | 718,163 | 651,863 |
| Accumulated other comprehensive loss | ( 704 ) | ( 704 ) |
| Total equity | 2,651,480 | 2,584,426 |
| Other long-term debt, excluding current maturities, net of issuance costs | 1,580,018 | 2,352,400 |
| Securitized utility tariff bonds, excluding current maturities, net of issuance costs | 295,555 | 309,343 |
| Total-long term debt, excluding current maturities, net of issuance costs | 1,875,573 | 2,661,743 |
| Total equity and long-term debt | 4,527,053 | 5,246,169 |
| Current liabilities |
| Current maturities of other long-term debt | 772,742 | 12 |
| Current maturities of securitized utility tariff bonds | 34,497 | 20,716 |
| Notes payable | 280,000 | 552,000 |
| Accounts payable | 197,619 | 360,493 |
| Accrued taxes other than income | 76,148 | 78,352 |
| Regulatory liabilities | 48,405 | 47,867 |
| Customer deposits | 56,467 | 57,854 |
| Other current liabilities | 76,397 | 72,125 |
| Total current liabilities | 1,542,275 | 1,189,419 |
| Deferred credits and other liabilities |
| Deferred income taxes | 720,640 | 698,456 |
| Regulatory liabilities | 516,625 | 529,441 |
| Employee benefit obligations | 19,599 | 19,587 |
| Other deferred credits | 94,060 | 93,324 |
| Total deferred credits and other liabilities | 1,350,924 | 1,340,808 |
| Commitments and contingencies |
| Total liabilities and equity | $ | 7,420,252 | $ | 7,776,396 |

See accompanying Notes to Consolidated Financial Statements.
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| ONE Gas, Inc. |
| CONSOLIDATED STATEMENTS OF CASH FLOWS |
| Three Months Ended |
| March 31, |
| (Unaudited) | 2023 | 2022 |
| (Thousands of dollars) |
| Operating activities |
| Net income | $ | 102,621 | $ | 98,934 |
| Adjustments to reconcile net income to net cash provided by operating activities: |
| Depreciation and amortization | 71,264 | 57,137 |
| Deferred income taxes | 9,364 | ( 6,849 ) |
| Share-based compensation expense | 2,821 | 2,695 |
| Provision for doubtful accounts | 3,925 | 1,338 |
| Proceeds from government securitization of winter weather event costs | 197,366 | — |
| Changes in assets and liabilities: |
| Accounts receivable | 56,336 | ( 154,278 ) |
| Materials and supplies | ( 2,160 ) | 705 |
| Natural gas in storage | 170,239 | 100,701 |
| Asset removal costs | ( 13,567 ) | ( 9,554 ) |
| Accounts payable | ( 157,533 ) | ( 56,863 ) |
| Accrued taxes other than income | ( 2,204 ) | 8,118 |
| Customer deposits | ( 1,387 ) | ( 1,349 ) |
| Regulatory assets and liabilities - current | 5,585 | 36,374 |
| Regulatory assets and liabilities - noncurrent | 21,871 | 66,002 |
| Other assets and liabilities - current | 3,573 | ( 12,438 ) |
| Other assets and liabilities - noncurrent | 952 | ( 23,037 ) |
| Cash provided by operating activities | 469,066 | 107,636 |
| Investing activities |
| Capital expenditures | ( 151,030 ) | ( 113,307 ) |
| Other investing expenditures | ( 292 ) | ( 608 ) |
| Other investing receipts | 1,443 | 549 |
| Cash used in investing activities | ( 149,879 ) | ( 113,366 ) |
| Financing activities |
| Borrowings (repayments) on notes payable, net | ( 272,000 ) | 11,165 |
| Issuance of common stock | — | 34,468 |
| Dividends paid | ( 36,002 ) | ( 33,285 ) |
| Tax withholdings related to net share settlements of stock compensation | ( 2,386 ) | ( 3,023 ) |
| Cash (used in) provided by financing activities | ( 310,388 ) | 9,325 |
| Change in cash, cash equivalents, restricted cash and restricted cash equivalents | 8,799 | 3,595 |
| Cash, cash equivalents, restricted cash and restricted cash equivalents at beginning of period | 18,127 | 8,852 |
| Cash, cash equivalents, restricted cash and restricted cash equivalents at end of period | $ | 26,926 | $ | 12,447 |
| Supplemental cash flow information: |
| Cash paid for interest, net of amounts capitalized | 33,729 | 28,017 |
| Cash paid (received) for income taxes, net | $ | ( 1,870 ) | $ | — |

See accompanying Notes to Consolidated Financial Statements.
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| ONE Gas, Inc. |
| CONSOLIDATED STATEMENTS OF EQUITY |
| (Unaudited) | Common Stock Issued | Common Stock | Paid-in Capital | Retained Earnings | Accumulated Other Comprehensive Income/(Loss) | Total Equity |
| (Shares) | (Thousands of dollars) |
| January 1, 2023 | 55,349,954 | $ | 553 | $ | 1,932,714 | $ | 651,863 | $ | ( 704 ) | $ | 2,584,426 |
| Net income | — | — | — | 102,621 | — | 102,621 |
| Common stock issued and other | 39,096 | — | 435 | — | — | 435 |
| Common stock dividends - $0.65 per share | — | — | 319 | ( 36,321 ) | — | ( 36,002 ) |
| March 31, 2023 | 55,389,050 | $ | 553 | $ | 1,933,468 | $ | 718,163 | $ | ( 704 ) | $ | 2,651,480 |
| January 1, 2022 | 53,633,210 | $ | 536 | $ | 1,790,362 | $ | 565,161 | $ | ( 6,527 ) | $ | 2,349,532 |
| Net income | — | — | — | 98,934 | — | 98,934 |
| Other comprehensive income | — | — | — | — | 69 | 69 |
| Common stock issued and other | 456,607 | 5 | 34,135 | — | — | 34,140 |
| Common stock dividends - $0.62 per share | — | — | 274 | ( 33,559 ) | — | ( 33,285 ) |
| March 31, 2022 | 54,089,817 | $ | 541 | $ | 1,824,771 | $ | 630,536 | $ | ( 6,458 ) | $ | 2,449,390 |

See accompanying Notes to Consolidated Financial Statements.
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ONE Gas, Inc.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
1. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES
Our accompanying unaudited consolidated financial statements have been prepared pursuant to the rules and regulations of the SEC. These statements also have been prepared in accordance with GAAP and reflect all adjustments that, in our opinion, are necessary for a fair statement of the results for the interim periods presented. All such adjustments are of a normal recurring nature. The 2022 year-end consolidated balance sheet data was derived from audited consolidated financial statements but does not include all disclosures required by GAAP. These unaudited consolidated financial statements should be read in conjunction with the audited consolidated financial statements and footnotes in our Annual Report. Our significant accounting policies are described in Note 1 of our Notes to Consolidated Financial Statements in our Annual Report. The preparation of these financial statements in conformity with GAAP requires management to make estimates and assumptions that affect the amounts and disclosures in the financial statements. Although management believes these estimates are reasonable, actual results could differ materially from these estimates. Due to the seasonal nature of our business, the results of operations for the three months ended March 31, 2023, are not necessarily indicative of the results that may be expected for a 12-month period.
We provide natural gas distribution services to approximately 2.3 million customers in Oklahoma, Kansas and Texas through our three divisions, Oklahoma Natural Gas, Kansas Gas Service and Texas Gas Service, respectively. We primarily serve residential, commercial and transportation customers in all three states.
Segments - We operate in one reportable business segment: regulated public utilities that deliver natural gas primarily to residential, commercial and transportation customers. Our accounting policies are the same as those described in Note 1 of the Notes to Consolidated Financial Statements in our Annual Report. We evaluate our financial performance principally on net income. For the three months ended March 31, 2023 and 2022, we had no single external customer from which we received 10 percent or more of our gross revenues.
Property, Plant and Equipment and Asset Removal Costs - Accounts payable for construction work in progress and asset removal costs decreased by approximately $ 5.3 million and $ 8.1 million for the three months ended March 31, 2023 and 2022, respectively. Such amounts are not included in capital expenditures or asset removal costs in our consolidated statements of cash flows.
Accounts Receivable - Accounts receivable represent valid claims against nonaffiliated customers for natural gas sold or services rendered, net of allowances for doubtful accounts. We assess the creditworthiness of our customers. Those customers who do not meet minimum standards may be required to provide security, including deposits and other forms of collateral, when appropriate and allowed by our tariffs. With approximately 2.3 million customers across three states, we are not exposed materially to a concentration of credit risk. We maintain an allowance for doubtful accounts based upon factors surrounding the credit risk of customers, historical trends, consideration of the current environment and other information. We recover natural gas costs related to accounts written off when they are deemed uncollectible through the purchased-gas cost adjustment mechanisms in each of our jurisdictions. At March 31, 2023 and December 31, 2022, our allowance for doubtful accounts was $ 19.7 million and $ 16.7 million, respectively.
Reclassifications -A reclassification has been made in the prior-year financial statements to conform to the current-year presentation. We have updated our consolidated balance sheet at December 31, 2022, to disaggregate “current maturities of other long-term debt,” which had previously been included in “other current liabilities,” to conform to our current-year presentation.
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2. REVENUE
The following table sets forth our revenues disaggregated by source for the periods indicated:
| Three Months Ended |
| March 31, |
| 2023 | 2022 |
| (Thousands of dollars) |
| Natural gas sales to customers | $ | 966,359 | $ | 925,157 |
| Transportation revenues | 38,527 | 36,316 |
| Securitization customer charges (Note 14) | 11,933 | — |
| Miscellaneous revenues | 5,898 | 4,496 |
| Total revenues from contracts with customers | 1,022,717 | 965,969 |
| Other revenues - natural gas sales related | 5,790 | 2,346 |
| Other revenues | 3,636 | 3,144 |
| Total other revenues | 9,426 | 5,490 |
| Total revenues | $ | 1,032,143 | $ | 971,459 |

Accrued unbilled natural gas sales revenues at March 31, 2023 and December 31, 2022, were $ 146.8 million and $ 269.5 million, respectively, and are included in accounts receivable on our consolidated balance sheets.
3. REGULATORY ASSETS AND LIABILITIES
The tables below present a summary of regulatory assets and liabilities, net of amortization, for the periods indicated:
| March 31, 2023 |
| Current | Noncurrent | Total |
| (Thousands of dollars) |
| Winter weather event costs | $ | 22,633 | $ | 28,577 | $ | 51,210 |
| Pension and postemployment benefit costs | 4,159 | 243,561 | 247,720 |
| Reacquired debt costs | 812 | 3,166 | 3,978 |
| MGP remediation costs | 98 | 29,719 | 29,817 |
| Ad-valorem tax | 11,386 | — | 11,386 |
| WNA | 7,994 | — | 7,994 |
| Customer credit deferrals | 15,475 | — | 15,475 |
| Other | 3,641 | 3,937 | 7,578 |
| Total regulatory assets, net of amortization | 66,198 | 308,960 | 375,158 |
| Income tax rate changes | — | ( 516,625 ) | ( 516,625 ) |
| Over-recovered purchased-gas costs | ( 48,405 ) | — | ( 48,405 ) |
| Total regulatory liabilities | ( 48,405 ) | ( 516,625 ) | ( 565,030 ) |
| Net regulatory assets and liabilities | $ | 17,793 | $ | ( 207,665 ) | $ | ( 189,872 ) |

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| December 31, 2022 |
| Current | Noncurrent | Total |
| (Thousands of dollars) |
| Winter weather event costs | $ | 221,926 | $ | 36,291 | $ | 258,217 |
| Under-recovered purchased-gas costs | 19,755 | — | 19,755 |
| Pension and postemployment benefit costs | — | 258,257 | 258,257 |
| Reacquired debt costs | 812 | 3,347 | 4,159 |
| MGP remediation costs | 98 | 29,743 | 29,841 |
| Ad-valorem tax | 13,359 | — | 13,359 |
| WNA | 8,474 | — | 8,474 |
| Customer credit deferrals | 9,504 | — | 9,504 |
| Other | 1,644 | 3,193 | 4,837 |
| Total regulatory assets, net of amortization | 275,572 | 330,831 | 606,403 |
| Pension and other postemployment benefit costs | ( 8,228 ) | — | ( 8,228 ) |
| Income tax rate changes | — | ( 529,441 ) | ( 529,441 ) |
| Over-recovered purchased-gas costs | ( 39,639 ) | — | ( 39,639 ) |
| Total regulatory liabilities | ( 47,867 ) | ( 529,441 ) | ( 577,308 ) |
| Net regulatory assets and liabilities | $ | 227,705 | $ | ( 198,610 ) | $ | 29,095 |

Regulatory assets in our consolidated balance sheets, as authorized by various regulatory authorities, are probable of recovery. Base rates and certain riders are designed to provide a recovery of costs during the period such rates are in effect, but do not generally provide for a return on investment for amounts we have deferred as regulatory assets. All of our regulatory assets are subject to review by the respective regulatory authorities during future regulatory proceedings. We are not aware of any evidence that these costs will not be recoverable through either riders, base rates, or securitization.
Winter weather event costs - In February 2021, the U.S. experienced Winter Storm Uri, a historic winter weather event impacting supply, market pricing and demand for natural gas in a number of states, including our service territories of Oklahoma, Kansas, and Texas. During this time, the governors of Oklahoma, Kansas, and Texas each declared a state of emergency, and certain regulatory agencies issued emergency orders that impacted the utility and natural gas industries, including statewide utility curtailment programs and orders requiring jurisdictional natural gas and electric utilities to do all things possible and necessary to ensure that natural gas and electricity utility services continued to be provided to their customers. Due to the historic nature of this winter weather event, we experienced unforeseeable and unprecedented market pricing for natural gas in our Oklahoma, Kansas, and Texas jurisdictions, which resulted in aggregated natural gas purchases for the month of February 2021 of approximately $ 2.1 billion.
Each state enacted securitization legislation to allow for recovery of the extraordinary gas costs, as well as other authorized expenses related to Winter Storm Uri. Securitization proceeds were received for Oklahoma and Kansas in 2022, and for Texas in 2023. See our Annual Report for more discussion of events surrounding Winter Storm Uri and the securitization of the related regulatory assets.
Kansas - In May 2021, Kansas Gas Service filed a motion in its company-specific docket opened by the KCC, requesting a limited waiver of the penalty provisions of its tariff to eliminate the multipliers in the penalty calculation when calculating the penalties to assess on marketers and individually-balanced transportation customers for their unauthorized natural gas usage during Winter Storm Uri. In March 2022, the KCC issued an order approving a settlement which modified the penalty provisions of Kansas Gas Service’s tariffs and included a carrying charge of two percent on amounts due to Kansas Gas Service. Amounts collected from these penalties will reduce the regulatory asset for the winter weather event, up to $ 52.6 million. Through March 31, 2023, we have collected $ 51.6 million of these penalties.
See Note 14 for additional information about the securitization transaction in Kansas.
Texas - Pursuant to securitization legislation enacted in Texas as a result of Winter Storm Uri and a June 2021 RRC Notice to Gas Utilities, Texas Gas Service submitted an application to the RRC in July 2021, for an order authorizing the amount of extraordinary costs for recovery and other such specifications necessary for the issuance of securitized bonds.
In February 2022, the RRC issued a single financing order for Texas Gas Service and other natural gas utilities in Texas participating in the securitization process, which included a determination that the approved costs will be collected from
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customers over a period of not more than 30 years. The TPFA formed the TNG Corporation, a new independent public authority, to issue the securitized bonds.
In March 2023, the TNG Corporation completed the issuance of the Customer Rate Relief (Winter Storm Uri), Taxable Series 2023 Bonds and we received our portion of the net proceeds, which was approximately $ 197 million. The proceeds were used to repay certain indebtedness and for general corporate purposes. Interest costs that exceeded the amount securitized have been deferred and will be addressed in the next general rate proceeding in each jurisdiction in Texas.
At March 31, 2023, Texas Gas Service had deferred approximately $ 36.1 million in extraordinary costs associated with Winter Storm Uri attributable to its former West Texas service area. Pursuant to the approved settlement order, Texas Gas Service began collecting the extraordinary costs, including carrying costs, from those customers in January 2022.
The deferred winter weather events costs also include invoiced costs for natural gas purchases during Winter Storm Uri that have not been paid as we work with our suppliers for Kansas and Texas to resolve discrepancies in invoiced amounts. These amounts may be adjusted as the differences with suppliers are resolved. Future adjustments to the amounts are not expected to have a material impact on earnings.
Other regulatory assets and liabilities - Purchased-gas costs represent the natural gas costs that have been over- or under-recovered from customers through the purchased-gas cost adjustment mechanisms, and includes natural gas utilized in our operations and premiums paid and any cash settlements received from our purchased natural gas call options.
The OCC, KCC and regulatory authorities in Texas have approved the recovery of pension costs and other postemployment benefits costs through rates for Oklahoma Natural Gas, Kansas Gas Service and Texas Gas Service, respectively. The costs recovered through rates are based on the net periodic benefit cost for defined benefit pension and other postemployment costs. Differences, if any, between the net periodic benefit cost, net of deferrals, and the amount recovered through rates are reflected in earnings. We historically have recovered defined benefit pension and other postemployment benefit costs through rates. We believe it is probable that regulators will continue to include the net periodic pension and other postemployment benefit costs in our cost of service.
We amortize reacquired debt costs in accordance with the accounting guidelines prescribed by the OCC and the KCC.
See Note 12 for additional information regarding our regulatory assets for MGP remediation costs.
Ad-valorem tax represents the difference in Kansas Gas Service’s taxes incurred each year above or below the amount approved in base rates. This difference is deferred as a regulatory asset or liability for a 12-month period. Kansas Gas Service then applies an adjustment to customers’ bills to refund the over-collected revenue or bill the under-collected revenue over the subsequent 12 months.
Weather normalization represents revenue over- or under-recovered through the WNA rider in Kansas. This amount is deferred as a regulatory asset or liability for a 12-month period. Kansas Gas Service then applies an adjustment to the customers’ bills for 12 months to refund the over-collected revenue or bill the under-collected revenue.
The customer credit deferrals and the noncurrent regulatory liability for income tax rate changes represents deferral of the effects of enacted federal and state income tax rate changes on our ADIT and the effects of these changes on our rates. See Note 10 for additional information regarding the impact of income tax rate changes.
Recovery through rates resulted in amortization of regulatory assets of approximately $ 7.0 million and $ 4.4 million for the three months ended March 31, 2023 and 2022, respectively.
4. CREDIT FACILITY AND SHORT-TERM DEBT
In March 2023, we entered into an extension agreement related to the ONE Gas Credit Agreement that extends the maturity date to March 16, 2028, from March 16, 2027. All other terms and conditions of the ONE Gas Credit Agreement remain in full force and effect.
The ONE Gas Credit Agreement provides for a $ 1.0 billion revolving unsecured credit facility and includes a $ 20 million letter of credit subfacility and a $ 60 million swingline subfacility. We can request an increase in commitments of up to an additional
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$ 500 million upon satisfaction of customary conditions, including receipt of commitments from either new lenders or increased commitments from existing lenders. The ONE Gas Credit Agreement is available to provide liquidity for working capital, capital expenditures, acquisitions and mergers, the issuance of letters of credit and for other general corporate purposes.
The ONE Gas Credit Agreement contains certain financial, operational and legal covenants. Among other things, these covenants include maintaining ONE Gas’ total debt-to-capital ratio of no more than 70 percent at the end of any calendar quarter. At March 31, 2023, our total debt-to-capital ratio was 53 percent and we were in compliance with all covenants under the ONE Gas Credit Agreement. We may reduce the unutilized portion of the ONE Gas Credit Agreement in whole or in part without premium or penalty. The ONE Gas Credit Agreement contains customary events of default. Upon the occurrence of certain events of default, the obligations under the ONE Gas Credit Agreement may be accelerated and the commitments may be terminated.
At March 31, 2023, we had $ 1.2 million in letters of credit issued and no borrowings under the ONE Gas Credit Agreement, with $ 998.8 million of remaining credit, which is available to repay any of our commercial paper borrowings.
We have a commercial paper program under which we may issue unsecured commercial paper up to a maximum amount of $ 1.0 billion to fund short-term borrowing needs. The maturities of the commercial paper vary but may not exceed 270 days from the date of issue. Commercial paper is generally sold at par less a discount representing an interest factor. At March 31, 2023 and December 31, 2022, we had $ 280.0 million and $ 552.0 million of commercial paper outstanding with a weighted-average interest rate of 5.41 percent and 4.75 percent, respectively.
5. LONG-TERM DEBT
The table below presents a summary of our long-term debt outstanding for the periods indicated:
| Interest rate at March 31, 2023 | March 31, 2023 | December 31, 2022 |
| (Thousands of dollars) |
| Senior unsecured notes: |
| Senior unsecured notes due February 2024 | 3.610 % | $ | 300,000 | $ | 300,000 |
| Senior unsecured notes due March 2024 | 1.100 % | 473,000 | 473,000 |
| Senior unsecured notes due May 2030 | 2.000 % | 300,000 | 300,000 |
| Senior unsecured notes due September 2032 | 4.250 % | 300,000 | 300,000 |
| Senior unsecured notes due February 2044 | 4.658 % | 600,000 | 600,000 |
| Senior unsecured notes due November 2048 | 4.500 % | 400,000 | 400,000 |
| Total senior unsecured notes | 2,373,000 | 2,373,000 |
| KGSS-I Securitized Utility Tariff Bonds | 5.486 % | 336,000 | 336,000 |
| Other | 8.000 % | 1,247 | 1,250 |
| Unamortized discounts on long-term debt | ( 7,531 ) | ( 7,636 ) |
| Debt issuance costs | ( 19,904 ) | ( 20,143 ) |
| Total long-term debt, net | 2,682,812 | 2,682,471 |
| Less: current maturities of securitized utility tariff bonds | 34,497 | 20,716 |
| Less: current maturities of long-term debt | 772,742 | 12 |
| Noncurrent portion of long-term debt, net | $ | 1,875,573 | $ | 2,661,743 |

Senior Notes - The indenture governing our Senior Notes includes an event of default upon the acceleration of other indebtedness of $ 100 million or more. Such events of default would entitle the trustee or the holders of 25 percent in aggregate principal amount of the outstanding Senior Notes to declare those Senior Notes immediately due and payable in full.
Depending on the series, we may redeem our Senior Notes at par, plus accrued and unpaid interest to the redemption date, starting three months or six months before their maturity dates. Prior to these dates, we may redeem these Senior Notes, in whole or in part, at a redemption price equal to the principal amount, plus accrued and unpaid interest and a make-whole premium. The redemption price will never be less than 100 percent of the principal amount of the respective Senior Note plus accrued and unpaid interest to the redemption date. Our Senior Notes are senior unsecured obligations, ranking equally in right of payment with all of our existing and future unsecured senior indebtedness.
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Securitized Utility Tariff Bonds - The KGSS-I Securitized Utility Tariff Bonds are governed by an indenture between KGSS-I and the indenture trustee. The indenture contains certain covenants that restrict KGSS-I’s ability to sell, transfer, convey, exchange, or otherwise dispose of its assets. See Note 14 for additional discussion of the Kansas securitization transaction.
6. EQUITY
Equity Forward Agreement - In March 2023, we entered into an underwriting agreement and a forward sale agreement for 2.0 million shares of our common stock. The forward sale agreement provides for settlement on a date, or dates, to be specified at our discretion, but which will occur no later than December 29, 2023, for 1.4 million shares of common stock and by December 31, 2024, for the remaining balance. Had we settled this forward agreement as of March 31, 2023, we would have generated net proceeds of approximately $152.7 million.
At-the-Market Equity Program - In February 2023, we entered into an at-the-market equity distribution agreement under which we may issue and sell shares of our common stock with an aggregate offering price up to $ 300 million (including any shares of common stock that may be sold pursuant to the master forward sale confirmation entered into in connection with the equity distribution agreement and the related supplemental confirmations). This at-the-market equity program replaced our previous at-the-market equity program, which began in February 2020, and expired in February 2023. The program allows us to offer and sell our common stock at prices we deem appropriate. Sales of common stock are made by means of ordinary brokers’ transactions on the NYSE, in block transactions or as otherwise agreed to between us and the sales agent. We are under no obligation to offer and sell common stock under the program. At March 31, 2023, we had $ 300 million of equity available for issuance under the program.
For the three months ended March 31, 2022, we issued and sold 403,792 shares of our common stock for $ 35.0 million, generating proceeds, net of issuance costs, of $ 34.7 million.
Had we settled all shares under our outstanding forward sale agreements as of March 31, 2023, we would have generated net proceeds of approximately $174.4 million, as detailed below:
| Maturity | Shares Sold | Net Proceeds Available(in thousands) | Forward Price |
| At-the-Market Equity Program |
| December 29, 2023 | 289,403 | $ | 21,748 | $ | 75.15 |
| Equity Forward Agreement |
| December 29, 2023 | 1,400,000 | 106,863 | 76.33 |
| December 31, 2024 | 600,000 | 45,798 | 76.33 |
| Total March 2023 Equity Forward Agreement | 2,000,000 | 152,661 | 76.33 |
| Total forward sale agreements | 2,289,403 | $ | 174,409 | $ | 76.18 |

Dividends Declared - In May 2023, we declared a dividend of $ 0.65 per share ($ 2.60 per share on an annualized basis) for shareholders of record as of May 17, 2023 , payable on June 2, 2023 .
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7. ACCUMULATED OTHER COMPREHENSIVE LOSS
The following table sets forth the effect of reclassifications from accumulated other comprehensive loss in our consolidated statements of income for the periods indicated:
| Three Months Ended | Affected Line Item in the |
| Details About Accumulated Other | March 31, | Consolidated Statements |
| Comprehensive Loss Components | 2023 | 2022 | of Income |
| (Thousands of dollars) |
| Pension and other postemployment benefit plan obligations (a) |
| Amortization of net loss | $ | 490 | $ | 8,201 |
| Amortization of unrecognized prior service cost (credit) | 131 | 10 |
| 621 | 8,211 |
| Regulatory adjustments (b) | ( 621 ) | ( 8,123 ) |
| — | 88 | Income before income taxes |
| — | ( 19 ) | Income tax expense |
| Total reclassifications for the period | $ | — | $ | 69 | Net income |

(a) These components of accumulated other comprehensive loss are included in the computation of net periodic benefit cost. See Note 9 for additional detail of our net periodic benefit cost.
(b) Regulatory adjustments represent pension and other postemployment benefit costs expected to be recovered through rates and are deferred as part of our regulatory assets. See Note 3 for additional disclosures of regulatory assets and liabilities.
8. EARNINGS PER SHARE
Basic EPS is calculated by dividing net income by the daily weighted-average number of common shares outstanding during the periods presented, which includes fully vested stock awards that have not yet been issued as common stock. Diluted EPS is based on shares outstanding for the calculation of basic EPS, plus unvested stock awards granted under our compensation plans and equity forward sale agreements, but only to the extent these instruments dilute earnings per share.
| Three Months Ended March 31, 2023 |
| Income | Shares | Per ShareAmount |
| (Thousands, except per share amounts) |
| Basic EPS Calculation |
| Net income available for common stock | $ | 102,621 | 55,538 | $ | 1.85 |
| Diluted EPS Calculation |
| Effect of dilutive securities | — | 262 |
| Net income available for common stock and common stock equivalents | $ | 102,621 | 55,800 | $ | 1.84 |
| Three Months Ended March 31, 2022 |
| Income | Shares | Per ShareAmount |
| (Thousands, except per share amounts) |
| Basic EPS Calculation |
| Net income available for common stock | $ | 98,934 | 53,922 | $ | 1.83 |
| Diluted EPS Calculation |
| Effect of dilutive securities | — | 108 |
| Net income available for common stock and common stock equivalents | $ | 98,934 | 54,030 | $ | 1.83 |

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9. EMPLOYEE BENEFIT PLANS
The following tables set forth the components of net periodic benefit cost for our pension and other postemployment benefit plans for the periods indicated:
| Pension Benefits |
| Three Months Ended |
| March 31, |
| 2023 | 2022 |
| (Thousands of dollars) |
| Components of net periodic benefit cost (credit) |
| Service cost | $ | 1,811 | $ | 3,094 |
| Interest cost | 10,607 | 7,804 |
| Expected return on assets | ( 14,879 ) | ( 14,613 ) |
| Amortization of unrecognized prior service cost | 93 | — |
| Amortization of net loss | 502 | 8,147 |
| Net periodic benefit cost (credit) | $ | ( 1,866 ) | $ | 4,432 |

| Other Postemployment Benefits |
| Three Months Ended |
| March 31, |
| 2023 | 2022 |
| (Thousands of dollars) |
| Components of net periodic benefit cost (credit) |
| Service cost | $ | 183 | $ | 318 |
| Interest cost | 2,288 | 1,612 |
| Expected return on assets | ( 2,432 ) | ( 3,295 ) |
| Amortization of unrecognized prior service cost | 38 | 10 |
| Amortization of net (gain) loss | ( 12 ) | 54 |
| Net periodic benefit cost (credit) | $ | 65 | $ | ( 1,301 ) |

We recover qualified pension benefit plan and other postemployment benefit plan costs through rates charged to our customers. Certain regulatory authorities require that the recovery of these costs be based on specific guidelines. The difference between these regulatory-based amounts and the periodic benefit cost calculated pursuant to GAAP is deferred as a regulatory asset or liability and amortized to expense over periods in which this difference will be recovered in rates, as authorized by the applicable regulatory authorities. For the three months ended March 31, 2023 and 2022, regulatory deferrals related to net periodic benefit cost were not material.
We capitalize all eligible service cost and non-service cost components under the accounting requirements of ASC Topic 980 (Regulated Operations) for rate-regulated entities. Our consolidated balance sheets reflect the capitalized non-service cost components as a regulatory asset in the amount of $ 1.4 million and $ 2.8 million at March 31, 2023 and December 31, 2022, respectively. See Note 3 of the Notes to Consolidated Financial Statements in this Quarterly Report for additional information.
10. INCOME TAXES
We use an estimated annual effective tax rate for purposes of determining the income tax provision during interim reporting periods. In calculating our estimated annual effective tax rate, we consider forecasted annual pre-tax income and estimated permanent book versus tax differences, as well as tax credits. Adjustments to the effective tax rate and estimates will occur as information and assumptions change.
At March 31, 2023, we have no uncertain tax positions. Changes in tax laws or tax rates are recognized in the financial reporting period that includes the enactment date. We are no longer subject to income tax examination for years prior to 2019.
Income tax expense reflects credits for the amortization of the regulatory liability associated with EDIT that was returned to customers of $ 9.9 million and $ 7.9 million for the three months ended March 31, 2023 and 2022, respectively.
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11. OTHER INCOME AND OTHER EXPENSE
The following table sets forth the components of other income and other expense for the periods indicated:
| Three Months Ended |
| March 31, |
| 2023 | 2022 |
| (Thousands of dollars) |
| Net periodic benefit (cost) credit other than service cost | $ | 908 | $ | ( 588 ) |
| Earnings (losses) on investments associated with nonqualified employee benefit plans | 1,613 | ( 2,833 ) |
| Other, net | 60 | ( 724 ) |
| Total other income (expense), net | $ | 2,581 | $ | ( 4,145 ) |

12. COMMITMENTS AND CONTINGENCIES
Environmental Matters - We are subject to multiple laws and regulations regarding protection of the environment and natural and cultural resources, which affect many aspects of our present and future operations. Regulated activities include, but are not limited to, those involving air emissions, storm water and wastewater discharges, handling and disposal of solid and hazardous wastes, wetland preservation, plant and wildlife protection, hazardous materials use, storage and transportation, and pipeline and facility construction. These laws and regulations require us to obtain and/or comply with a wide variety of environmental clearances, registrations, licenses, permits and other approvals. Failure to comply with these laws, regulations, licenses and permits or the discovery of presently unknown environmental conditions may expose us to fines, penalties and/or interruptions in our operations that could be material to our results of operations. In addition, emission controls and/or other regulatory or permitting mandates under the CAA and other similar federal and state laws could require unexpected capital expenditures. We cannot assure that existing environmental statutes and regulations will not be revised or that new regulations will not be adopted or become applicable to us. Revised or additional statutes or regulations that result in increased compliance costs or additional operating restrictions could have a material adverse effect on our business, financial condition and results of operations. Our expenditures for environmental investigation and remediation compliance to-date have not been significant in relation to our financial position, results of operations or cash flows, and our expenditures related to environmental matters had no material effects on earnings or cash flows during the three months ended March 31, 2023 and 2022.
We own or retain legal responsibility for certain environmental conditions at 12 former MGP sites in Kansas. These sites contain contaminants generally associated with MGP sites and are subject to control or remediation under various environmental laws and regulations. A consent agreement with the KDHE governs all environmental investigation and remediation work at these sites. The terms of the consent agreement require us to investigate these sites and set remediation activities based upon the results of the investigations and risk analysis. Remediation typically involves the management of contaminated soils and may involve removal of structures and monitoring and/or remediation of groundwater. Regulatory closure has been achieved at five of the 12 sites, but these sites remain subject to potential future requirements that may result in additional costs.
We have an AAO that allows Kansas Gas Service to defer and seek recovery of costs necessary for investigation and remediation at, and nearby, these 12 former MGP sites that are incurred after January 1, 2017, up to a cap of $ 15.0 million, net of any related insurance recoveries. Costs approved for recovery in a future rate proceeding would then be amortized over a 15-year period. The unamortized amounts will not be included in rate base or accumulate carrying charges. Following a determination that future investigation and remediation work approved by the KDHE is expected to exceed $ 15.0 million, net of any related insurance recoveries, Kansas Gas Service will be required to file an application with the KCC for approval to increase the $ 15.0 million cap. At March 31, 2023 and December 31, 2022, we have deferred $ 29.8 million for accrued investigation and remediation costs pursuant to our AAO. Kansas Gas Service expects to file an application as soon as practicable after the KDHE approves the plans we have submitted.
We have completed or are addressing removal of the source of soil contamination at all 12 sites and continue to monitor groundwater at seven of the 12 sites according to plans approved by the KDHE. In 2019, we completed a project to remove a source of contamination and associated contaminated materials at the twelfth site where no active soil remediation had previously occurred. In 2022, we completed a remediation project to remove a source of contamination and contaminated materials at one of the MGP sites. Remediation plans concerning various sites were submitted to the KDHE in 2021 and 2020 and the KDHE has provided comments that we are addressing. We are also working on a remediation plan for an additional site for submission to the KDHE.
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We also own or retain legal responsibility for certain environmental conditions at a former MGP site in Texas. At the request of the TCEQ, we began investigating the level and extent of contamination associated with the site under their Texas Risk Reduction Program. A preliminary site investigation revealed that this site contains contaminants generally associated with MGP sites and is subject to control or remediation under various environmental laws and regulations. Impacts have been identified in the soil and groundwater at the site with limited impacts observed in surrounding areas. In April 2022, we submitted a remediation work plan to address the areas impacted to the TCEQ. At March 31, 2023, estimated costs associated with expected remediation activities for this site are not material.
Our expenditures for environmental evaluation, mitigation, remediation and compliance to date have not been significant in relation to our financial position, results of operations or cash flows, and our expenditures related to environmental matters had no material effects on earnings or cash flows during the three months ended March 31, 2023 and 2022. The reserve for remediation of our MGP sites was $ 12.7 million at March 31, 2023 and December 31, 2022.
Pipeline Safety - We are subject to regulation under federal pipeline safety statutes and any analogous state regulations. These include safety requirements for the design, construction, operation, and maintenance of pipelines, including transmission and distribution pipelines. At the federal level, we are regulated by PHMSA. PHMSA regulations require the following for certain pipelines: inspection and maintenance plans; integrity management programs, including the determination of pipeline integrity risks and periodic assessments on certain pipeline segments; an operator qualification program, which includes certain trainings; a public awareness program that provides certain information; and a control room management plan.
As part of the Consolidated Appropriations Act, 2021, the PIPES Act reauthorized PHMSA through 2023 and directed the agency to move forward with several regulatory actions, including the “Pipeline Safety: Class Location Change Requirements” and the “Pipeline Safety: Safety of Gas Transmission and Gathering Pipelines” proposed rulemakings. Congress has also instructed PHMSA to issue final regulations that will require operators of non-rural gas gathering lines and new and existing transmission and distribution pipeline facilities to conduct certain leak detection and repair programs and to require facility inspection and maintenance plans to align with those regulations. To the extent such rulemakings impose more stringent requirements on our facilities, we may be required to incur expenditures that may be material.
Legal Proceedings - We are a party to various litigation matters and claims that have arisen in the normal course of our operations. While the results of litigation and claims cannot be predicted with certainty, we believe the reasonably possible losses from such matters, individually and in the aggregate, are not material. Additionally, we believe the probable outcome of such matters will not have a material adverse effect on our results of operations, financial position or cash flows.
13. DERIVATIVE FINANCIAL INSTRUMENTS AND FAIR VALUE MEASUREMENTS
Accounting Treatment - We record all derivative instruments at fair value, with the exception of normal purchases and normal sales that are expected to result in physical delivery. The accounting for changes in the fair value of a derivative instrument depends on whether it has been designated and qualifies as part of a hedging relationship and, if so, the reason for holding it, or if regulatory requirements impose a different accounting treatment.
If certain conditions are met, we may elect to designate a derivative instrument as a hedge of exposure to changes in fair values or cash flows. We have not elected to designate any of our derivative instruments as hedges.
The table below summarizes the various ways in which we account for our derivative instruments and the impact on our consolidated financial statements:
| Recognition and Measurement |
| Accounting Treatment | Balance Sheet | Income Statement |
| Normal purchases andnormal sales | - | Fair value not recorded | - | Change in fair value not recognized in earnings |
| Mark-to-market | - | Recorded at fair value | - | Change in fair value recognized in, and recoverable through, the purchased-gas cost adjustment mechanisms |

Fair Value Measurements - We define fair value as the price that would be received from the sale of an asset or the transfer of a liability in an orderly transaction between market participants at the measurement date. We use the market and income approaches to determine the fair value of our assets and liabilities and consider the markets in which the transactions are
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executed. We measure the fair value of a group of financial assets and liabilities consistent with how a market participant would price the net risk exposure at the measurement date.
Fair Value Hierarchy - At each balance sheet date, we utilize a fair value hierarchy to classify fair value amounts recognized or disclosed in our consolidated financial statements based on the observability of inputs used to estimate such fair value. The levels of the hierarchy are described below:
•Level 1 - Unadjusted quoted prices in active markets for identical assets or liabilities;
•Level 2 - Significant observable pricing inputs other than quoted prices included within Level 1 that are, either directly or indirectly, observable as of the reporting date. Essentially, this represents inputs that are derived principally from or corroborated by observable market data; and
•Level 3 - May include one or more unobservable inputs that are significant in establishing a fair value estimate. These unobservable inputs are developed based on the best information available and may include our own internal data.
We recognize transfers into and out of the levels as of the end of each reporting period.
Determining the appropriate classification of our fair value measurements within the fair value hierarchy requires management’s judgment regarding the degree to which market data is observable or corroborated by observable market data. We categorize derivatives for which fair value is determined using multiple inputs within a single level, based on the lowest level input that is significant to the fair value measurement in its entirety.
Derivative Instruments - At March 31, 2023, we had no purchased natural gas call options. At December 31, 2022, we held purchased natural gas call options for the heating season ended March 2023, with total notional amounts of 19.4 Bcf, for which we paid premiums of $ 14.1 million, and which had no fair value. These contracts are included in, and recoverable through, our purchased-gas cost adjustment mechanisms. Additionally, premiums paid, changes in fair value and any settlements received associated with these contracts are deferred as part of our unrecovered purchased-gas costs in our consolidated balance sheets. Our natural gas call options are classified as Level 1, as fair value amounts are based on unadjusted quoted prices in active markets including settled prices on the New York Mercantile Exchange. There were no transfers between levels for the periods presented.
Other Financial Instruments - The approximate fair value of cash and cash equivalents, restricted cash and cash equivalents, accounts receivable and accounts payable is equal to book value, due to the short-term nature of these items. Our cash and cash equivalents and restricted cash and cash equivalents are comprised of cash and money market accounts, which are classified as Level 1.
We record certain financial assets and liabilities at fair value at each balance sheet date. The table below summarizes the balances of these assets at March 31, 2023 and December 31, 2022:
| March 31, 2023 |
| Level 1 | Level 2 | Total |
| Other Current Assets: |
| United States treasury notes | $ | 726 | $ | — | $ | 726 |
| Corporate bonds | — | 2,359 | 2,359 |
| Other Assets: |
| United States treasury notes | 3,326 | — | 3,326 |
| Corporate bonds | — | 6,913 | 6,913 |

| December 31, 2022 |
| Level 1 | Level 2 | Total |
| Other Current Assets: |
| United States treasury notes | $ | 1,204 | $ | — | $ | 1,204 |
| Corporate bonds | — | 2,086 | 2,086 |
| Other Assets: |
| United States treasury notes | 3,491 | — | 3,491 |
| Corporate bonds | — | 7,624 | 7,624 |

Commercial paper is due upon demand and, therefore, the carrying amounts approximate fair value and are classified as Level 1. The estimated fair value of our long-term debt, including current maturities, was $ 2.5 billion at March 31, 2023 and
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December 31, 2022. The estimated fair value of our long-term debt was determined using quoted market prices, and is classified as Level 2.
14. VARIABLE INTEREST ENTITY
KGSS-I is a special-purpose, wholly owned subsidiary of ONE Gas that was formed for the purpose of issuing securitized utility tariff bonds to recover extraordinary costs incurred by Kansas Gas Service resulting from Winter Storm Uri. On November 18, 2022, the securitized financing was complete. KGSS-I’s assets cannot be used to settle ONE Gas’ obligations and the holders of the Securitized Utility Tariff Bonds have no recourse against ONE Gas. See Note 5 for additional information about the securitization financing.
Because KGSS-I’s equity at risk is less than 1 percent of its total assets, it is considered to be a variable interest entity. Through its equity ownership interest and role as servicer, ONE Gas has the power to direct the most significant financial and operating activities of KGSS-I, including billing, collections, and remittance of customer cash receipts to enable KGSS-I to service the principal and interest payments due under the Securitized Utility Tariff Bonds. Therefore, ONE Gas is the primary beneficiary of KGSS-I, and as a result, KGSS-I is included in the consolidated financial statements of ONE Gas. No gain or loss was recognized upon initial consolidation.
The following table summarizes the impact of KGSS-I on our consolidated balance sheets, for the periods indicated:
| March 31, | December 31, |
| 2023 | 2022 |
| (Thousands of dollars) |
| Restricted cash and cash equivalents | $ | 19,117 | $ | 8,446 |
| Accounts receivable | 4,051 | 4,862 |
| Securitized intangible asset, net | 316,749 | 323,838 |
| Current maturities of securitized utility tariff bonds | 34,497 | 20,716 |
| Accounts payable | 1,374 | 3,204 |
| Accrued interest | 6,810 | 2,202 |
| Securitized utility tariff bonds, excluding current maturities, net of issuance costs | 295,555 | 309,343 |
| Equity | 1,681 | 1,681 |

The following table summarizes the impact of KGSS-I on our consolidated statements of income, for the period indicated:
| Three Months Ended |
| March 31, |
| 2023 |
| (Thousands of dollars) |
| Operating revenues | $ | 11,933 |
| Operating expense | ( 110 ) |
| Amortization expense | ( 7,089 ) |
| Interest income | 75 |
| Interest expense | ( 4,809 ) |
| Income before income taxes | $ | — |

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ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS
The following discussion and analysis should be read in conjunction with our unaudited consolidated financial statements and the Notes to Consolidated Financial Statements in this Quarterly Report, as well as our Annual Report. Due to the seasonal nature of our business, the results of operations for the three months ended March 31, 2023, are not necessarily indicative of the results that may be expected for a 12-month period.
RECENT DEVELOPMENTS
Securitization transaction - In March 2023, the TNG Corporation completed the issuance of the Customer Rate Relief (Winter Storm Uri), Taxable Series 2023 Bonds. On March 23, 2023, we received our portion of the net proceeds, which was approximately $197 million. The proceeds were used to repay certain indebtedness and for general corporate purposes.
See “Regulatory Activities,” and Note 3 of the Notes to Consolidated Financial Statements in this Quarterly Report for additional discussion of the securitization transaction.
Equity forward agreement - In March 2023, we entered into an underwriting agreement and a forward sale agreement for 2.0 million shares of our common stock. The forward sale agreement provides for settlement on a date, or dates, to be specified at our discretion, but which will occur no later than December 29, 2023, for 1.4 million shares of common stock and by December 31, 2024, for the remaining balance. Had we settled this forward agreement as of March 31, 2023, we would have generated net proceeds of approximately $152.7 million.
At-the-market equity program - In February 2023, we entered into an at-the-market equity distribution agreement under which we may issue and sell shares of our common stock with an aggregate offering price up to $300 million (including any shares of common stock that may be sold pursuant to the master forward sale confirmation entered into in connection with the equity distribution agreement and the related supplemental confirmations). This at-the-market equity program replaced our previous at-the-market equity program, which began in February 2020, and expired in February 2023. The program allows us to offer and sell our common stock at prices we deem appropriate. Sales of common stock are made by means of ordinary brokers’ transactions on the NYSE, in block transactions or as otherwise agreed to between us and the sales agent. We are under no obligation to offer and sell common stock under the program. At March 31, 2023, we had $300 million of equity available for issuance under the program.
ONE Gas Credit Agreement - In March 2023, we entered into an extension agreement related to the ONE Gas Credit Agreement that extends the maturity date to March 16, 2028, from March 16, 2027. All other terms and conditions of the ONE Gas Credit Agreement remain in full force and effect.
Dividend - In May 2023, we declared a dividend of $0.65 per share ($2.60 per share on an annualized basis) for shareholders of record as of May 17, 2023, payable on June 2, 2023.
REGULATORY ACTIVITIES
Oklahoma - As required, PBRC filings are made annually on or before March 15 until the next general rate case, which is required to be filed on or before June 30, 2027. In March 2023, Oklahoma Natural Gas filed its required PBRC application for the year ended December 2022. The filed request includes a $27.6 million base rate revenue increase, $2.5 million energy efficiency incentive, and $11.9 million of estimated EDIT to be credited to customers in 2024. A hearing is scheduled for June 15, 2023.
In December 2022, Oklahoma Natural Gas filed a request for an RNG Pilot Program and Voluntary Tariff pursuant to the requirement in the rate case order approved in 2021. The proposed tariff will allow all residential, small commercial and industrial sales customers to voluntarily purchase the environmental attributes of RNG up to the equivalent of 10 Dth per month. If approved, the tariff will be in effect through 2027. Assessment of the tariff and pilot program will be made in the rate case required to be filed on or before June 30, 2027. An order is expected no earlier than the third quarter of 2023.
Texas - Pursuant to securitization legislation enacted in Texas as a result of Winter Storm Uri and a June 2021 RRC Notice to Gas Utilities, Texas Gas Service submitted an application to the RRC in July 2021, for an order authorizing the amount of extraordinary costs for recovery and other such specifications necessary for the issuance of securitized bonds.
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In February 2022, the RRC issued a single financing order for Texas Gas Service and other natural gas utilities in Texas participating in the securitization process, which included a determination that the approved costs will be collected from customers over a period of not more than 30 years. The TPFA formed the TNG Corporation, a new independent public authority, to issue the securitized bonds.
In March 2023, the TNG Corporation completed the issuance of the Customer Rate Relief (Winter Storm Uri), Taxable Series 2023 Bonds and we received our portion of the net proceeds, which was approximately $197 million. The proceeds were used to repay certain indebtedness and for general corporate purposes. Interest costs that exceeded the amount securitized have been
deferred and will be addressed in the next general rate proceeding in each jurisdiction in Texas.
Central-Gulf Service Area - In February 2023, Texas Gas Service made GRIP filings for all customers in the Central-Gulf service area, requesting an $11.5 million increase to be effective in June 2023.
West-North Service Area - In March 2023, Texas Gas Service made GRIP filings for all customers in the West-North service area, requesting a $7.4 million increase to be effective in July 2023.
In June 2022, Texas Gas Service filed a rate case seeking to consolidate its West Texas, North Texas and Borger/Skellytown service areas into a single West-North service area and requesting a rate increase of $13.0 million. In January 2023, the RRC approved the consolidation and a rate increase of $8.8 million premised on a return on equity of 9.6 percent and a common equity ratio of 59.74 percent equity. The new rates were implemented in February 2023.
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FINANCIAL RESULTS AND OPERATING INFORMATION
We operate in one reportable business segment: regulated public utilities that deliver natural gas to residential, commercial and transportation customers. Our accounting policies are the same as described in Note 1 of the Notes to Consolidated Financial Statements in our Annual Report. We evaluate our financial performance principally on net income.
Selected Financial Results - For the three months ended March 31, 2023, net income was $102.6 million, or $1.84 per diluted share, compared with $98.9 million, or $1.83 per diluted share, in the same period last year.
The following table sets forth certain selected financial results for our operations for the periods indicated:
| Three Months Ended | Three Months |
| March 31, | 2023 vs. 2022 |
| Financial Results | 2023 | 2022 | Increase (Decrease) |
| (Millions of dollars, except percentages) |
| Natural gas sales | $ | 971.8 | $ | 927.0 | $ | 44.8 | 5 | % |
| Transportation revenues | 38.9 | 36.8 | 2.1 | 6 | % |
| Securitization customer charges | 11.9 | — | 11.9 | 100 | % |
| Other revenues | 9.5 | 7.6 | 1.9 | 25 | % |
| Total revenues | 1,032.1 | 971.4 | 60.7 | 6 | % |
| Cost of natural gas | 665.8 | 639.9 | 25.9 | 4 | % |
| Operating costs | 145.8 | 133.6 | 12.2 | 9 | % |
| Depreciation and amortization | 71.3 | 57.1 | 14.2 | 25 | % |
| Operating income | $ | 149.2 | $ | 140.8 | $ | 8.4 | 6 | % |
| Capital expenditures and asset removal costs | $ | 164.6 | $ | 122.9 | $ | 41.7 | 34 | % |

Natural gas sales to customers represent revenue from contracts with customers through implied contracts established by our tariffs and rates approved by regulatory authorities, as well as revenues from regulatory mechanisms related to natural gas sales. Additionally, natural gas sales include recovery of the cost of natural gas.
Our natural gas sales include fixed and variable charges related to the delivery of natural gas and gas costs that are passed through to our customers in accordance with our cost of natural gas regulatory mechanisms. Fixed charges reflect the portion of our natural gas sales attributable to the monthly fixed customer charge component of our rates, which does not fluctuate based on customer usage in each period. Variable charges reflect the portion of our natural gas sales that fluctuate with the volumes delivered and billed and the effects of weather normalization.
Securitization customer charges represent revenue from contracts with customers through implied contracts established by the financing order approved by the KCC, related to the securitization of extraordinary costs incurred during Winter Storm Uri in the state of Kansas. See Note 14 of the Notes to Consolidated Financial Statements in this Quarterly Report for additional discussion of the securitization transaction in Kansas.
Transportation revenues represent revenue from contracts with customers through implied contracts established by our tariffs and rates approved by regulatory authorities, as well as tariff-based negotiated contracts.
Other revenues include primarily miscellaneous service charges, which represent implied contracts with customers established by our tariffs and rates approved by regulatory authorities and other revenues from regulatory mechanisms.
Cost of natural gas includes commodity purchases, fuel, storage, transportation, hedging costs and settlement proceeds for natural gas price volatility mitigation programs approved by our regulators and other gas purchase costs recovered through our cost of natural gas regulatory mechanisms and does not include an allocation of general operating costs or depreciation and amortization. These regulatory mechanisms provide a method of recovering natural gas costs on an ongoing basis without a profit. Therefore, although our revenues will fluctuate with the cost of natural gas that we pass-through to our customers, operating income is not affected by fluctuations in the cost of natural gas.
Operating income increased $8.4 million for the three months ended March 31, 2023, compared with the same period last year, due primarily to the following:
•an increase of $17.3 million from new rates; and
•a decrease of $1.6 million in COVID-19 related expenses.
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These increases were offset partially by:
•an increase of $4.5 million in depreciation expense due to additional capital expenditures being placed in service;
•an increase of $4.1 million in employee-related costs; and
•an increase of $2.6 million in bad debt expense.
Weather across our service territories for the first quarter was 14.5% warmer than the prior year. Due to our weather normalization mechanisms, the impact on operating income was not material.
Revenues include an increase of $11.9 million associated with KGSS-I, which is offset by $7.1 million in amortization expense and $4.8 million in interest expense. Revenues also include an increase of $2.5 million due to the annual adjustment of the ad-valorem rider for Kansas Gas Service, which is offset in amortization expense.
Other Factors Affecting Net Income - Other factors that affected net income for the three months ended March 31, 2023, compared with the same period last year, include an increase of $6.7 million in other income offset by an increase of $14.5 million in interest expense. The increase in other income, net, is due primarily to a $4.4 million increase in the market value of investments associated with our nonqualified employee benefit plans and a $1.5 million decrease in net periodic benefit costs other than service costs. The increase in interest expense is due primarily to an increase in the weighted average interest rate on our commercial paper and the issuance of $300 million of 4.25 percent senior notes in August 2022 and $336 million of 5.486 percent Securitized Utility Tariff Bonds in November 2022.
EDIT - Income tax expense reflects credits for the amortization of the regulatory liability associated with EDIT that was returned to customers of $9.9 million and $7.9 million for the three months ended March 31, 2023 and 2022, respectively.
Capital Expenditures and Asset Removal Costs - Our capital expenditures program includes expenditures for pipeline integrity, extending service to new areas, increasing system capabilities, pipeline replacements, automated meter reading, government-mandated pipeline relocations, fleet, facilities, IT assets and cybersecurity. It is our practice to maintain and upgrade our infrastructure, facilities and systems to ensure safe, reliable and efficient operations. Asset removal costs include expenditures associated with the replacement or retirement of long-lived assets that result from the construction, development and/or normal use of our assets, primarily our pipeline assets. While we have not experienced a significant impact to our capital expenditures program in the three months ended March 31, 2023, our capital expenditure activity for the remainder of the year could experience a delay if economic conditions worsen, impacting our supply chain for contract labor, materials and supplies.
Capital expenditures and asset removal costs were $41.7 million higher for the three months ended March 31, 2023, compared with the same period last year, due primarily to expenditures for system integrity and extension of service to new areas. Our full-year capital expenditures and asset removal costs are expected to be approximately $675 million for 2023.
Selected Operating Information - The following tables set forth certain selected operating information for the periods indicated:
| Three Months Ended | Variances |
| March 31, | 2023 vs. 2022 |
| (in thousands) | 2023 | 2022 | Increase (Decrease) |
| Average Number of Customers | OK | KS | TX | Total | OK | KS | TX | Total | OK | KS | TX | Total |
| Residential | 841 | 599 | 660 | 2,100 | 834 | 598 | 654 | 2,086 | 7 | 1 | 6 | 14 |
| Commercial and industrial | 78 | 51 | 36 | 165 | 77 | 51 | 36 | 164 | 1 | — | — | 1 |
| Other | — | — | 3 | 3 | — | — | 3 | 3 | — | — | — | — |
| Transportation | 5 | 6 | 1 | 12 | 5 | 6 | 1 | 12 | — | — | — | — |
| Total customers | 924 | 656 | 700 | 2,280 | 916 | 655 | 694 | 2,265 | 8 | 1 | 6 | 15 |

The increase in the average number of customers for the periods presented is due primarily to the connection of new customers resulting from the extension and expansion of our system in our service areas. For the three months ended March 31, 2023, our average customer count includes approximately 5,800 new customer connections during the period. For the year ended December 31, 2022, our average customer count included approximately 27,100 new customer connections.
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The following table reflects total volumes delivered, excluding the effects of WNA mechanisms on sales volumes:
| Three Months Ended |
| March 31, |
| Volumes (MMcf) | 2023 | 2022 |
| Natural gas sales |
| Residential | 54,603 | 60,650 |
| Commercial and industrial | 18,143 | 19,369 |
| Other | 1,088 | 1,111 |
| Total sales volumes delivered | 73,834 | 81,130 |
| Transportation | 64,934 | 67,071 |
| Total volumes delivered | 138,768 | 148,201 |

The impact of weather on residential and commercial natural gas sales is mitigated by WNA mechanisms in all jurisdictions.
The following table sets forth the HDDs by state for the periods indicated:
| Three Months Ended |
| March 31, |
| 2023 | 2022 | 2023 vs. 2022 | 2023 | 2022 |
| HDDs | Actual | Normal | Actual | Normal | Actual Variance | Actual as a percent of Normal |
| Oklahoma | 1,719 | 1,792 | 1,985 | 1,792 | (13) | % | 96 | % | 111 | % |
| Kansas | 2,251 | 2,460 | 2,532 | 2,461 | (11) | % | 92 | % | 103 | % |
| Texas | 902 | 985 | 1,182 | 999 | (24) | % | 92 | % | 118 | % |

Normal HDDs are established through rate proceedings in each of our jurisdictions for use primarily in weather normalization billing calculations. See further discussion on weather normalization in our Regulatory Overview section in Part 1, Item 1, “Business,” of our Annual Report. Normal HDDs disclosed above are based on:
•Oklahoma - A 10-year weighted average as of June 30, 2021, as calculated using 11 weather stations across Oklahoma and weighted on average customer count.
•Kansas - A 30-year rolling average for years 1988-2017 calculated using three weather stations across Kansas and weighted on HDDs by weather station and customers.
•Texas - An average of HDDs authorized in our most recent rate proceeding in each jurisdiction and weighted using a rolling 10-year average of actual natural gas distribution sales volumes by service area.
Actual HDDs are based on the quarter-to-date weighted average of:
•11 weather stations and customers by month for Oklahoma;
•3 weather stations and customers by month for Kansas; and
•9 weather stations and natural gas distribution sales volumes by service area for Texas.
CONTINGENCIES
We are a party to various litigation matters and claims that have arisen in the normal course of our operations. While the results of litigation and claims cannot be predicted with certainty, we believe the reasonably possible losses from such matters, individually and in the aggregate, are not material. Additionally, we believe the probable outcome of such matters will not have a material adverse effect on our results of operations, financial position or cash flows.
LIQUIDITY AND CAPITAL RESOURCES
General - We have relied primarily on operating cash flow and commercial paper for our liquidity and capital resource requirements. We fund operating expenses, working capital requirements, including purchases of natural gas, and capital expenditures primarily with cash from operations and commercial paper.
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We believe that the combination of the significant residential component of our customer base, the fixed-charge component of our natural gas sales revenues and our rate mechanisms that we have in place result in a stable cash flow profile and historically has generated stable earnings. Additionally, we have rate mechanisms in place in our jurisdictions that reduce the lag in earning a return on our capital expenditures and provide for recovery of certain changes in our cost of service by allowing for adjustments to rates between rate cases. We anticipate that our cash flow generated from operations and our expected short- and long-term financing arrangements will enable us to maintain our current and planned level of operations and provide us flexibility to finance our infrastructure investments. Our ability to access capital markets for debt and equity financing under reasonable terms depends on market conditions, our financial condition and credit ratings.
Short-term Debt - In March 2023, we entered into an extension agreement related to the ONE Gas Credit Agreement that extends the maturity date to March 16, 2028, from March 16, 2027. All other terms and conditions of the ONE Gas Credit Agreement remain in full force and effect.
The ONE Gas Credit Agreement provides for a $1.0 billion revolving unsecured credit facility and includes a $20 million letter of credit subfacility and a $60 million swingline subfacility. We can request an increase in commitments of up to an additional
$500 million upon satisfaction of customary conditions, including receipt of commitments from either new lenders or increased commitments from existing lenders. The ONE Gas Credit Agreement is available to provide liquidity for working capital, capital expenditures, acquisitions and mergers, the issuance of letters of credit and for other general corporate purposes.
The ONE Gas Credit Agreement contains certain financial, operational and legal covenants. Among other things, these covenants include maintaining ONE Gas’ total debt-to-capital ratio of no more than 70 percent at the end of any calendar quarter. At March 31, 2023, our total debt-to-capital ratio was 53 percent and we were in compliance with all covenants under the ONE Gas Credit Agreement. We may reduce the unutilized portion of the ONE Gas Credit Agreement in whole or in part without premium or penalty. The ONE Gas Credit Agreement contains customary events of default. Upon the occurrence of certain events of default, the obligations under the ONE Gas Credit Agreement may be accelerated and the commitments may be terminated.
We have a commercial paper program under which we may issue unsecured commercial paper up to a maximum amount of $1.0 billion to fund short-term borrowing needs. The maturities of the commercial paper vary but may not exceed 270 days from the date of issue. Commercial paper is generally sold at par less a discount representing an interest factor. At March 31, 2023 and December 31, 2022, we had $280.0 million and $552.0 million of commercial paper outstanding with a weighted-average interest rate of 5.41 percent and 4.75 percent, respectively.
At March 31, 2023, we had $1.2 million in letters of credit issued and no borrowings under the ONE Gas Credit Agreement, with $998.8 million of remaining credit, which is available to repay any of our commercial paper borrowings.
Senior Notes - At March 31, 2023, we had outstanding $2.4 billion of Senior Notes with $772.7 million due within the next year. The indenture governing our Senior Notes includes an event of default upon the acceleration of other indebtedness of $100 million or more. Such events of default would entitle the trustee or the holders of 25 percent in aggregate principal amount of the outstanding Senior Notes to declare those Senior Notes immediately due and payable in full.
Depending on the series, we may redeem our Senior Notes at par, plus accrued and unpaid interest to the redemption date, starting three months or six months before their maturity dates. Prior to these dates, we may redeem these Senior Notes, in whole or in part, at a redemption price equal to the principal amount, plus accrued and unpaid interest and a make-whole premium. The redemption price will never be less than 100 percent of the principal amount of the respective Senior Note plus accrued and unpaid interest to the redemption date. Our Senior Notes are senior unsecured obligations, ranking equally in right of payment with all of our existing and future unsecured senior indebtedness.
Securitized Utility Tariff Bonds - At March 31, 2023, we had outstanding $336.0 million of 5.486 percent Securitized Utility Tariff Bonds with $34.5 million due within the next year. The bonds are governed by an indenture between KGSS-I and the indenture trustee. The indenture contains certain covenants that restrict KGSS-I’s ability to sell, transfer, convey, exchange, or otherwise dispose of its assets.
At March 31, 2023, our long-term debt-to-capital ratio was 50 percent. Excluding the debt of KGSS-I, which is non-recourse to us, our long-term debt-to-capital ratio was 47 percent.
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Credit Ratings - Our credit ratings at March 31, 2023, were:
| Rating Agency | Rating | Outlook |
| Moody’s | A3 | Stable |
| S&P | A- | Stable |

At March 31, 2023, our commercial paper was rated Prime-2 by Moody’s and A-2 by S&P. We intend to maintain credit metrics at a level that supports our balanced approach to capital investment and a return of capital to shareholders via a dividend that we believe will be competitive with our peer group.
Equity forward agreement - In March 2023, we entered into an underwriting agreement and a forward sale agreement for 2.0 million shares of our common stock. The forward sale agreement provides for settlement on a date, or dates, to be specified at our discretion, but which will occur no later than December 29, 2023, for 1.4 million shares of common stock and by December 31, 2024, for the remaining balance. Had we settled this forward agreement as of March 31, 2023, we would have generated net proceeds of approximately $152.7 million.
At-the-market equity program - In February 2023, we entered into an at-the-market equity distribution agreement under which we may issue and sell shares of our common stock with an aggregate offering price up to $300 million (including any shares of common stock that may be sold pursuant to the master forward sale confirmation entered into in connection with the equity distribution agreement and the related supplemental confirmations). This at-the-market equity program replaced our previous at-the-market equity program, which began in February 2020, and expired in February 2023. The program allows us to offer and sell our common stock at prices we deem appropriate. Sales of common stock are made by means of ordinary brokers’ transactions on the NYSE, in block transactions or as otherwise agreed to between us and the sales agent. We are under no obligation to offer and sell common stock under the program. At March 31, 2023, we had $300 million of equity available for issuance under the program.
Had we settled all shares under our outstanding forward sale agreements, including those outstanding under our previous at-the-market equity program, as of March 31, 2023, we would have generated net proceeds of approximately $174.4 million, as detailed below:
| Maturity | Shares Sold | Net Proceeds Available(in thousands) | Forward Price |
| At-the-Market Equity Program |
| December 29, 2023 | 289,403 | $ | 21,748 | $ | 75.15 |
| Equity Forward Agreement |
| December 29, 2023 | 1,400,000 | 106,863 | 76.33 |
| December 31, 2024 | 600,000 | 45,798 | 76.33 |
| Total March 2023 Equity Forward Agreement | 2,000,000 | 152,661 | 76.33 |
| Total forward sale agreements | 2,289,403 | $ | 174,409 | $ | 76.18 |

Pension and Other Postemployment Benefit Plans - In 2023, our contributions are expected to be approximately $1.4 million to our defined benefit pension plans, and no contributions are expected to be made to our other postemployment benefit plans. We use a December 31 measurement date for our plans.
Information about our pension and other postemployment benefits plans is included under Note 14 of the Notes to Consolidated Financial Statements in our Annual Report. See Note 9 of the Notes to Consolidated Financial Statements in this Quarterly Report for additional information.
CASH FLOW ANALYSIS
We use the indirect method to prepare our consolidated statements of cash flows. Under this method, we reconcile net income to cash flows provided by operating activities by adjusting net income for those items that impact net income but may not result in actual cash receipts or payments and changes in our assets and liabilities not classified as investing or financing activities during the period. Items that impact net income but may not result in actual cash receipts or payments include, but are not
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limited to, depreciation and amortization, deferred income taxes, share-based compensation expense and provision for doubtful accounts.
The following table sets forth the changes in cash flows by operating, investing and financing activities for the periods indicated:
| Three Months Ended |
| March 31, | Variance |
| 2023 | 2022 | 2023 vs. 2022 |
| (Millions of dollars) |
| Total cash provided by (used in): |
| Operating activities | $ | 469.1 | $ | 107.6 | $ | 361.5 |
| Investing activities | (149.9) | (113.4) | (36.5) |
| Financing activities | (310.4) | 9.3 | (319.7) |
| Change in cash, cash equivalents, restricted cash and restricted cash equivalents | 8.8 | 3.5 | 5.3 |
| Cash, cash equivalents, restricted cash and restricted cash equivalents at beginning of period | 18.1 | 8.9 | 9.2 |
| Cash, cash equivalents, restricted cash and restricted cash equivalents at end of period | $ | 26.9 | $ | 12.4 | $ | 14.5 |

Operating Cash Flows - Changes in cash flows from operating activities are due primarily to changes in sales revenues, natural gas costs and operating expenses discussed in Financial Results and Operating Information, the effects of Winter Storm Uri discussed in Regulatory Activities and changes in working capital. Changes in natural gas prices and demand for our services or natural gas, whether because of general economic conditions, variations in weather not mitigated by WNAs, changes in supply or increased competition from other service providers, could affect our earnings and operating cash flows. Typically, our cash flows from operations are greater in the first half of the year compared with the second half of the year.
Operating cash flows were higher for the three months ended March 31, 2023, compared with the prior period, due primarily to recovery of the winter weather event regulatory asset for Texas Gas Service through securitization and working capital changes related to accounts receivable which were impacted by new rates in the current period compared with the same period in 2022.
Investing Cash Flows - Cash used in investing activities increased for the three months ended March 31, 2023, due primarily to an increase in capital expenditures for system integrity and extension of service to new areas.
Financing Cash Flows - Cash used in financing activities increased for the three months ended March 31, 2023, compared with the prior period, due primarily to increased repayments of notes payable.
ENVIRONMENTAL, SAFETY AND REGULATORY MATTERS
Environmental Matters - We are subject to multiple laws and regulations regarding protection of the environment and natural and cultural resources, which affect many aspects of our present and future operations. Regulated activities include, but are not limited to, those involving air emissions, storm water and wastewater discharges, handling and disposal of solid and hazardous wastes, wetland preservation, plant and wildlife protection, hazardous materials use, storage and transportation, and pipeline and facility construction. These laws and regulations require us to obtain and/or comply with a wide variety of environmental clearances, registrations, licenses, permits and other approvals. Failure to comply with these laws, regulations, licenses and permits or the discovery of presently unknown environmental conditions may expose us to fines, penalties and/or interruptions in our operations that could be material to our results of operations. In addition, emission controls and/or other regulatory or permitting mandates under the CAA and other similar federal and state laws could require unexpected capital expenditures. We cannot assure that existing environmental statutes and regulations will not be revised or that new regulations will not be adopted or become applicable to us. Revised or additional statutes or regulations that result in increased compliance costs or additional operating restrictions could have a material adverse effect on our business, financial condition and results of operations. Our expenditures for environmental investigation and remediation compliance to-date have not been significant in relation to our financial position, results of operations or cash flows, and our expenditures related to environmental matters had no material effects on earnings or cash flows during the three months ended March 31, 2023 and 2022.
We own or retain legal responsibility for certain environmental conditions at 12 former MGP sites in Kansas. These sites contain contaminants generally associated with MGP sites and are subject to control or remediation under various environmental laws and regulations. A consent agreement with the KDHE governs all environmental investigation and
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remediation work at these sites. The terms of the consent agreement require us to investigate these sites and set remediation activities based upon the results of the investigations and risk analysis. Remediation typically involves the management of contaminated soils and may involve removal of structures and monitoring and/or remediation of groundwater. Regulatory closure has been achieved at five of the 12 sites, but these sites remain subject to potential future requirements that may result in additional costs.
We have an AAO that allows Kansas Gas Service to defer and seek recovery of costs necessary for investigation and remediation at, and nearby, these 12 former MGP sites that are incurred after January 1, 2017, up to a cap of $15.0 million, net of any related insurance recoveries. Costs approved for recovery in a future rate proceeding would then be amortized over a 15-year period. The unamortized amounts will not be included in rate base or accumulate carrying charges. Following a determination that future investigation and remediation work approved by the KDHE is expected to exceed $15.0 million, net of any related insurance recoveries, Kansas Gas Service will be required to file an application with the KCC for approval to increase the $15.0 million cap. At March 31, 2023 and December 31, 2022, we have deferred $29.8 million for accrued investigation and remediation costs pursuant to our AAO. Kansas Gas Service expects to file an application as soon as practicable after the KDHE approves the plans we have submitted.
We have completed or are addressing removal of the source of soil contamination at all 12 sites and continue to monitor groundwater at seven of the 12 sites according to plans approved by the KDHE. In 2019, we completed a project to remove a source of contamination and associated contaminated materials at the twelfth site where no active soil remediation had previously occurred. Remediation plans concerning various sites were submitted to the KDHE in 2021 and 2020 and the KDHE has provided comments that we are addressing. We are also working on a remediation plan for another of these sites for submission to the KDHE.
We also own or retain legal responsibility for certain environmental conditions at a former MGP site in Texas. At the request of the TCEQ, we began investigating the level and extent of contamination associated with the site under their Texas Risk Reduction Program. A preliminary site investigation revealed that this site contains contaminants generally associated with MGP sites and is subject to control or remediation under various environmental laws and regulations. Impacts have been identified in the soil and groundwater at the site with limited impacts observed in surrounding areas. In April 2022, we submitted a remediation work plan to address the areas impacted to the TCEQ. At March 31, 2023, estimated costs associated with expected remediation activities for this site are not material.
Our expenditures for environmental evaluation, mitigation, remediation and compliance to date have not been significant in relation to our financial position, results of operations or cash flows, and our expenditures related to environmental matters had no material effects on earnings or cash flows during the three months ended March 31, 2023 and 2022. The reserve for remediation of our MGP sites was $12.7 million at March 31, 2023 and December 31, 2022.
Environmental Footprint - We cannot assure that existing environmental statutes and regulations will not be revised or that new regulations will not be adopted or become applicable to us. Revised or additional regulations that result in increased compliance costs or additional operating restrictions could have a material adverse effect on our business, financial condition and results of operations. Our expenditures for environmental investigation, and remediation compliance to-date have not been significant in relation to our financial position, results of operations or cash flows, and our expenditures related to environmental matters had no material effects on earnings or cash flows for the three months ended March 31, 2023 and 2022.
Pipeline Safety - We are subject to regulation under federal pipeline safety statutes and any analogous state regulations. These include safety requirements for the design, construction, operation, and maintenance of pipelines, including transmission and distribution pipelines. At the federal level, we are regulated by PHMSA. PHMSA regulations require the following for certain pipelines: inspection and maintenance plans; integrity management programs, including the determination of pipeline integrity risks and periodic assessments on certain pipeline segments; an operator qualification program, which includes certain trainings; a public awareness program that provides certain information; and a control room management plan.
As part of the Consolidated Appropriations Act, 2021, the PIPES Act reauthorized PHMSA through 2023 and directed the agency to move forward with several regulatory actions, including the “Pipeline Safety: Class Location Change Requirements” and the “Pipeline Safety: Safety of Gas Transmission and Gathering Pipelines” proposed rulemakings. Congress has also instructed PHMSA to issue final regulations that will require operators of non-rural gas gathering lines and new and existing transmission and distribution pipeline facilities to conduct certain leak detection and repair programs and to require facility inspection and maintenance plans to align with those regulations. To the extent such rulemakings impose more stringent requirements on our facilities, we may be required to incur expenditures that may be material.
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Regulatory - Several regulatory initiatives impacted the earnings and future earnings potential of our business. See additional information regarding our regulatory initiatives in the “Regulatory Activities” section of Management’s Discussion and Analysis of Financial Condition and Results of Operations.
IMPACT OF NEW ACCOUNTING STANDARDS
Information about the impact of new accounting standards, if any, is included in Note 1 of the Notes to Consolidated Financial Statements in this Quarterly Report.
CRITICAL ESTIMATES AND ACCOUNTING POLICIES
The preparation of our consolidated financial statements and related disclosures in accordance with GAAP requires us to make estimates and assumptions with respect to values or conditions that cannot be known with certainty that affect the reported amounts of assets and liabilities and the disclosure of contingent assets and liabilities at the date of the consolidated financial statements. These estimates and assumptions also affect the reported amounts of revenues and expenses during the reporting period. Although we believe these estimates and assumptions are reasonable, actual results could differ from our estimates.
Information about our estimates and critical accounting policies is included under Item 7, Management’s Discussion and Analysis of Financial Condition and Results of Operations, “Estimates and Critical Accounting Policies,” in our Annual Report.
FORWARD-LOOKING STATEMENTS
Some of the statements contained and incorporated in this Quarterly Report are forward-looking statements within the meaning of Section 27A of the Securities Act and Section 21E of the Exchange Act. The forward-looking statements relate to our anticipated financial performance, liquidity, management’s plans and objectives for our future operations, our business prospects, the outcome of regulatory and legal proceedings, market conditions and other matters. We make these forward-looking statements in reliance on the safe harbor protections provided under the Private Securities Litigation Reform Act of 1995. The following discussion is intended to identify important factors that could cause future outcomes to differ materially from those set forth in the forward-looking statements.
Forward-looking and other statements in this Quarterly Report regarding our environmental, social and other sustainability plans and goals are not an indication that these statements are necessarily material to investors or required to be disclosed in our filings with the SEC. In addition, historical, current, and forward-looking environmental, social and sustainability-related statements may be based on standards for measuring progress that are still developing, internal controls and processes that continue to evolve, and assumptions that are subject to change in the future.
Forward-looking statements include the items identified in the preceding paragraph, the information concerning possible or assumed future results of our operations and other statements contained or incorporated in this Quarterly Report identified by words such as “anticipate,” “estimate,” “expect,” “project,” “intend,” “plan,” “believe,” “should,” “goal,” “forecast,” “guidance,” “could,” “may,” “continue,” “might,” “potential,” “scheduled,” “likely,” and other words and terms of similar meaning.
One should not place undue reliance on forward-looking statements, which are applicable only as of the date of this Quarterly Report. Known and unknown risks, uncertainties and other factors may cause our actual results, performance or achievements to be materially different from any future results, performance or achievements expressed or implied by forward-looking statements. Those factors may affect our operations, costs, liquidity, markets, products, services and prices. In addition to any assumptions and other factors referred to specifically in connection with the forward-looking statements, factors that could cause our actual results to differ materially from those contemplated in any forward-looking statement include, among others, the following:
•our ability to recover costs, income taxes and amounts equivalent to the cost of property, plant and equipment, regulatory assets and our allowed rate of return in our regulated rates or other recovery mechanisms;
•cyber-attacks, which, according to experts, continue to increase in volume and sophistication, or breaches of technology systems that could disrupt our operations or result in the loss or exposure of confidential or sensitive customer, employee or Company information; further, increased remote working arrangements have required enhancements and modifications to our IT infrastructure (e.g. Internet, Virtual Private Network, remote collaboration systems, etc.), and any failures of the technologies, including third-party service providers, that facilitate working remotely could limit our ability to conduct ordinary operations or expose us to increased risk or effect of an attack;
•our ability to manage our operations and maintenance costs;
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•the concentration of our operations in Oklahoma, Kansas, and Texas;
•changes in regulation of natural gas distribution services, particularly those in Oklahoma, Kansas and Texas;
•the economic climate and, particularly, its effect on the natural gas requirements of our residential and commercial customers;
•the length and severity of a pandemic or other health crisis which could significantly disrupt or prevent us from operating our business in the ordinary course for an extended period;
•competition from alternative forms of energy, including, but not limited to, electricity, solar power, wind power, geothermal energy and biofuels;
•adverse weather conditions and variations in weather, including seasonal effects on demand and/or supply, the occurrence of severe storms in the territories in which we operate, and climate change, and the related effects on supply, demand, and costs;
•indebtedness could make us more vulnerable to general adverse economic and industry conditions, limit our ability to borrow additional funds and/or place us at competitive disadvantage compared with competitors;
•our ability to secure reliable, competitively priced and flexible natural gas transportation and supply, including decisions by natural gas producers to reduce production or shut-in producing natural gas wells and expiration of existing supply and transportation and storage arrangements that are not replaced with contracts with similar terms and pricing;
•our ability to complete necessary or desirable expansion or infrastructure development projects, which may delay or prevent us from serving our customers or expanding our business;
•operational and mechanical hazards or interruptions;
•adverse labor relations;
•the effectiveness of our strategies to reduce earnings lag, revenue protection strategies and risk mitigation strategies, which may be affected by risks beyond our control such as commodity price volatility, counterparty performance or creditworthiness and interest rate risk;
•the capital-intensive nature of our business, and the availability of and access to, in general, funds to meet our debt obligations prior to or when they become due and to fund our operations and capital expenditures, either through (i) cash on hand, (ii) operating cash flow, or (iii) access to the capital markets and other sources of liquidity;
•our ability to obtain capital on commercially reasonable terms, or on terms acceptable to us, or at all;
•limitations on our operating flexibility, earnings and cash flows due to restrictions in our financing arrangements;
•cross-default provisions in our borrowing arrangements, which may lead to our inability to satisfy all of our outstanding obligations in the event of a default on our part;
•changes in the financial markets during the periods covered by the forward-looking statements, particularly those affecting the availability of capital and our ability to refinance existing debt and fund investments and acquisitions to execute our business strategy;
•actions of rating agencies, including the ratings of debt, general corporate ratings and changes in the rating agencies’ ratings criteria;
•changes in inflation and interest rates;
•our ability to recover the costs of natural gas purchased for our customers and any related financing required to support our purchase of natural gas supply;
•impact of potential impairment charges;
•volatility and changes in markets for natural gas and our ability to secure additional and sufficient liquidity on reasonable commercial terms to cover costs associated with such volatility;
•possible loss of LDC franchises or other adverse effects caused by the actions of municipalities;
•payment and performance by counterparties and customers as contracted and when due, including our counterparties maintaining ordinary course terms of supply and payments;
•changes in existing or the addition of new environmental, safety, tax and other laws to which we and our subsidiaries are subject, including those that may require significant expenditures, significant increases in operating costs or, in the case of noncompliance, substantial fines or penalties;
•the effectiveness of our risk-management policies and procedures, and employees violating our risk-management policies;
•the uncertainty of estimates, including accruals and costs of environmental remediation;
•advances in technology, including technologies that increase efficiency or that improve electricity’s competitive position relative to natural gas;
•population growth rates and changes in the demographic patterns of the markets we serve, and economic conditions in these areas’ housing markets;
•acts of nature and the potential effects of threatened or actual terrorism and war, including recent events in Europe;
•the sufficiency of insurance coverage to cover losses;
•the effects of our strategies to reduce tax payments;
•changes in accounting standards;
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•changes in corporate governance standards;
•existence of material weaknesses in our internal controls;
•our ability to comply with all covenants in our indentures and the ONE Gas Credit Agreement, a violation of which, if not cured in a timely manner, could trigger a default of our obligations;
•our ability to attract and retain talented employees, management and directors, and shortage of skilled-labor;
•unexpected increases in the costs of providing health care benefits, along with pension and postemployment health care benefits, as well as declines in the discount rates on, declines in the market value of the debt and equity securities of, and increases in funding requirements for, our defined benefit plans; and
•our ability to successfully complete merger, acquisition or divestiture plans, regulatory or other limitations imposed as a result of a merger, acquisition or divestiture, and the success of the business following a merger, acquisition or divestiture.
These factors are not necessarily all of the important factors that could cause actual results to differ materially from those expressed in any of our forward-looking statements. Other factors could also have material adverse effects on our future results. These and other risks are described in greater detail in Part 1, Item 1A, Risk Factors, in our Annual Report. All forward-looking statements attributable to us or persons acting on our behalf are expressly qualified in their entirety by these factors. Other than as required under securities laws, we undertake no obligation to update publicly any forward-looking statement whether as a result of new information, subsequent events or change in circumstances, expectations or otherwise.
ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK
Our quantitative and qualitative disclosures about market risk are consistent with those discussed in Part II, Item 7A, Quantitative and Qualitative Disclosures About Market Risk, in our Annual Report.
Commodity Price Risk
Our commodity price risk, driven primarily by fluctuations in the price of natural gas, is mitigated by our purchased-gas cost adjustment mechanisms through which we pass-through natural gas costs to our customers without profit. We may use derivative instruments to hedge the cost of a portion of our anticipated natural gas purchases during the winter heating months to reduce the impact on our customers of upward market price volatility of natural gas. Additionally, we inject natural gas into storage during the warmer months, when natural gas prices are typically lower, and withdraw the natural gas during the colder months of the year. Gains or losses associated with these derivative instruments and storage activities are included in, and recoverable through our purchased-gas cost adjustment mechanisms, which are subject to review by regulatory authorities.
Interest-Rate Risk
We are exposed to interest-rate risk primarily associated with commercial paper borrowings, borrowings under our credit agreement, and new debt financing needed to fund capital requirements, including future contractual obligations and maturities of long-term and short-term debt. We may manage interest-rate risk on future borrowings through the use of fixed-rate debt, floating-rate debt and, at times, interest-rate swaps. Fixed-rate swaps may be used to reduce our risk of increased interest costs during periods of rising interest rates. Floating-rate swaps may be used to convert the fixed rates of long-term borrowings into short-term variable rates.
Counterparty Credit Risk
We assess the creditworthiness of our customers. Those customers who do not meet minimum standards are required to provide security, including deposits or other forms of collateral, when appropriate and allowed by tariff. With approximately 2.3 million customers across three states, we are not exposed materially to a concentration of credit risk. We maintain a provision for doubtful accounts based upon factors surrounding the credit risk of customers, historical trends, consideration of the current credit environment and other information. We are able to recover the fuel-related portion of bad debts through our purchased-gas cost adjustment mechanisms.
ITEM 4.
CONTROLS AND PROCEDURES
Quarterly Evaluation of Disclosure Controls and Procedures - Our Chief Executive Officer (Principal Executive Officer) and Chief Financial Officer (Principal Financial Officer) have concluded that our disclosure controls and procedures were effective as of the end of the period covered by this report based on the evaluation of the controls and procedures required by Rules 13(a)-15(b) of the Exchange Act.
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Changes in Internal Control Over Financial Reporting - There have been no changes in our internal control over financial reporting during the first quarter ended March 31, 2023, that have materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.
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PART II - OTHER INFORMATION
ITEM 1. LEGAL PROCEEDINGS
We are a party to various litigation matters and claims that have arisen in the normal course of our operations. While the results of litigation and claims cannot be predicted with certainty, we believe the reasonably possible losses from such matters, individually and in the aggregate, are not material. Additionally, we believe the probable final outcome of such matters will not have a material adverse effect on our results of operations, financial position or cash flows.
ITEM 1A. RISK FACTORS
Our investors should consider the risks set forth in Part I, Item 1A, Risk Factors, of our Annual Report that could affect us and our business. Although we have tried to discuss key factors, our investors need to be aware that other risks may prove to be important in the future. New risks may emerge at any time, and we cannot predict such risks or estimate the extent to which they may affect our financial performance. Investors should carefully consider the discussion of risks and the other information included or incorporated by reference in this Quarterly Report, including “Forward-Looking Statements,” which are included in Part I, Item 2, Management’s Discussion and Analysis of Financial Condition and Results of Operations.
ITEM 2.
UNREGISTERED SALES OF EQUITY SECURITIES AND USE OF PROCEEDS
Not applicable.
ITEM 3. DEFAULTS UPON SENIOR SECURITIES
Not applicable.
ITEM 4. MINE SAFETY DISCLOSURES
Not applicable.
ITEM 5. OTHER INFORMATION
Not applicable.
ITEM 6.
EXHIBITS
Readers of this report should not rely on or assume the accuracy of any representation or warranty or the validity of any opinion contained in any agreement filed as an exhibit to this Quarterly Report, because such representation, warranty or opinion may be subject to exceptions and qualifications contained in separate disclosure schedules, may represent an allocation of risk between parties in the particular transaction, may be qualified by materiality standards that differ from what may be viewed as material for securities law purposes, or may no longer continue to be true as of any given date. All exhibits attached to this Quarterly Report are included for the purpose of complying with requirements of the SEC. Other than the certifications made by our officers pursuant to the Sarbanes-Oxley Act of 2002 included as exhibits to this Quarterly Report, all exhibits are included only to provide information to investors regarding their respective terms and should not be relied upon as constituting or providing any factual disclosures about us, any other persons, any state of affairs or other matters.
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The following exhibits are filed as part of this Quarterly Report:
| Exhibit No. | Exhibit Description |
| 3.1 | Amended Certificate of Incorporation of ONE Gas, Inc., dated May 24, 2018 (incorporated by reference to Exhibit 3.1 to ONE Gas, Inc.’s Current Report on Form 8-K filed on May 30, 2018 (File No. 1-36108)). |
| 3.2 | Amended and Restated By-Laws of ONE Gas, Inc. dated February 21, 2023 (incorporated by reference to Exhibit 3.1 to ONE Gas, Inc.’s Current Report on Form 8-K filed on February 21, 2023 (File No. 1-36108)). |
| 10.1 | Form of 2023 Restricted Unit Award Agreement (incorporated by reference to Exhibit 10.10 to ONE Gas, Inc.’s Annual Report on Form 10-K filed on February 23, 2023 (File No. 1-36108)). |
| 10.2 | Form of 2023 Performance Unit Award Agreement (incorporated by reference to Exhibit 10.11 to ONE Gas, Inc.’s Annual Report on Form 10-K filed on February 23, 2023 (File No. 1-36108)). |
| 10.3 | Equity Distribution Agreement, dated as of February 24, 2023, among ONE Gas, Inc. and BofA Securities, Inc., J.P. Morgan Securities LLC, Mizuho Securities USA LLC and RBC Capital Markets, LLC acting as managers; Bank of America, N.A., JPMorgan Chase Bank, National Association, Mizuho Markets Americas LLC and Royal Bank of Canada, acting as forward purchasers; and BofA Securities, Inc., J.P. Morgan Securities LLC, Mizuho Securities USA LLC, and RBC Capital Markets, LLC acting as forward sellers (incorporated by reference to Exhibit 1.1 to ONE Gas, Inc.’s Current Report on Form 8-K filed on February 24, 2023 (File No. 1-36108)). |
| 10.4 | Equity Underwriting Agreement, dated as of March 8, 2023, among ONE Gas, Inc. and BofA Securities, Inc., acting as the underwriter, BofA Securities, Inc., acting as the forward seller, and Bank of America, N.A., acting as the forward purchaser (incorporated by reference to Exhibit 1.1 to ONE Gas, Inc.’s Current Report on Form 8-K filed on March 13, 2023 (File No. 1-36108). |
| 10.5 | Confirmation of Forward Sale Transaction, dated as of March 8, 2023, between ONE Gas, Inc. and Bank of America, N.A. (incorporated by reference to Exhibit 10.1 to ONE Gas, Inc.’s Current Report on Form 8-K filed on March 13, 2023 (File No. 1-36108). |
| 10.6 | Extension Agreement, dated as of March 16, 2023, among ONE Gas, Inc., Bank of America, N.A., as administrative agent, swing line lender, and a letter of credit issuer, and the other lenders and letter of credit issuers parties thereto (incorporated by reference to Exhibit 10.1 to ONE Gas, Inc.’s Current Report on Form 8-K filed on March 16, 2023 (File No. 1-36108). |
| 31.1 | Certification of Robert S. McAnnally pursuant to Section 302 of the Sarbanes-Oxley Act of 2002. |
| 31.2 | Certification of Caron A. Lawhorn pursuant to Section 302 of the Sarbanes-Oxley Act of 2002. |
| 32.1 | Certification of Robert S. McAnnally pursuant to 18 U.S.C. Section 1350 as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002 (furnished only pursuant to Rule 13a-14(b)). |
| 32.2 | Certification of Caron A. Lawhorn pursuant to 18 U.S.C. Section 1350 as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002 (furnished only pursuant to Rule 13a-14(b)). |

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| 101.INS | 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 | XBRL Schema Document. |
| 101.CAL | XBRL Calculation Linkbase Document. |
| 101.LAB | XBRL Label Linkbase Document. |
| 101.PRE | XBRL Presentation Linkbase Document. |
| 101.DEF | XBRL Extension Definition Linkbase Document. |
| 104 | Cover Page Interactive Data File (embedded within the Inline XBRL document and contained in Exhibit 101). |

Attached as Exhibit 101 to this Quarterly Report are the following XBRL-related documents: (i) Document and Entity Information; (ii) Consolidated Statements of Income for the three months ended months ended March 31, 2023 and 2022; (iii) Consolidated Statements of Comprehensive Income for the three months ended months ended March 31, 2023 and 2022; (iv) Consolidated Balance Sheets at March 31, 2023 and December 31, 2022; (v) Consolidated Statements of Cash Flows for the three months ended March 31, 2023 and 2022; (vi) Consolidated Statements of Equity for the three months ended months ended March 31, 2023 and 2022; and (vii) Notes to Consolidated Financial Statements.
We also make available on our website the Interactive Data Files submitted as Exhibit 101 to this Quarterly Report.
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SIGNATURE
Pursuant to the requirements of the Exchange Act, the registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized.
| Date: May 2, 2023 | ONE Gas, Inc. |
| Registrant |
| By: | /s/ Caron A. Lawhorn |
| Caron A. Lawhorn |
| Senior Vice President and |
| Chief Financial Officer |
| (Principal Financial Officer) |

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Question: If ONE Gas, Inc. continued to operate with the same financial performance as it did in the 1st quarter of 2023, how much would the estimated change of cash and cash equivalents be by the end of year 2023 compared to the beginning of 2023, considering the dividends that will be paid on June 2, 2023? (in thousands of dollars)

Solution:
def solution():
    q1_change_in_cash = 8799  
    beginning_cash = 18127 
    dividends_paid = 36002 

    #Do math calculation to get the answer
    estimated_annual_change = q1_change_in_cash * 4  
    estimated_end_cash = beginning_cash + estimated_annual_change - dividends_paid  
    answer = estimated_end_cash
    return answer


Answer: 17321