Cover Page
Cover Page - shares | 3 Months Ended | |
Mar. 31, 2022 | Apr. 25, 2022 | |
Document Information [Line Items] | ||
Document Type | 10-Q | |
Entity Registrant Name | ONE Gas, Inc. | |
Entity Central Index Key | 0001587732 | |
Current Fiscal Year End Date | --12-31 | |
Document Fiscal Year Focus | 2022 | |
Document Fiscal Period Focus | Q1 | |
Amendment Flag | false | |
Entity Information [Line Items] | ||
Document Quarterly Report | true | |
Document Period End Date | Mar. 31, 2022 | |
Document Transition Report | false | |
Entity File Number | 001-36108 | |
Entity Incorporation, State or Country Code | OK | |
Entity Tax Identification Number | 46-3561936 | |
Entity Address, Address Line One | 15 East Fifth Street | |
Entity Address, City or Town | Tulsa, | |
Entity Address, State or Province | OK | |
Entity Address, Postal Zip Code | 74103 | |
City Area Code | (918) | |
Local Phone Number | 947-7000 | |
Title of 12(b) Security | Common Stock, par value $0.01 per share | |
Trading Symbol | OGS | |
Security Exchange Name | NYSE | |
Entity Current Reporting Status | Yes | |
Entity Interactive Data Current | Yes | |
Entity Filer Category | Large Accelerated Filer | |
Entity Small Business | false | |
Entity Emerging Growth Company | false | |
Entity Shell Company | false | |
Entity Common Stock, Shares Outstanding | 54,089,905 |
STATEMENTS OF INCOME
STATEMENTS OF INCOME - USD ($) shares in Thousands, $ in Thousands | 3 Months Ended | |
Mar. 31, 2022 | Mar. 31, 2021 | |
Regulated Operating Revenue | $ 971,459 | $ 625,293 |
Cost of natural gas | 639,946 | 314,069 |
Operating expenses | ||
Operations and maintenance | 115,095 | 110,886 |
Depreciation and amortization | 57,137 | 52,266 |
General taxes | 18,524 | 17,727 |
Total operating expenses | 190,756 | 180,879 |
Operating income | 140,757 | 130,345 |
Other expense, net | (4,145) | (405) |
Interest expense, net | (15,595) | (15,440) |
Income before income taxes | 121,017 | 114,500 |
Income taxes | (22,083) | (18,925) |
Net income | $ 98,934 | $ 95,575 |
Earnings per share | ||
Basic | $ 1.83 | $ 1.79 |
Diluted | $ 1.83 | $ 1.79 |
Weighted Average Number of Shares Outstanding, Basic [Abstract] | ||
Basic | 53,922 | 53,372 |
Weighted Average Number of Shares Outstanding, Diluted [Abstract] | ||
Diluted | 54,030 | 53,515 |
Common Stock, Dividends, Per Share, Declared | $ 0.62 | $ 0.58 |
STATEMENTS OF COMPREHENSIVE INC
STATEMENTS OF COMPREHENSIVE INCOME STATEMENTS OF COMPREHENSIVE INCOME - USD ($) $ in Thousands | 3 Months Ended | |
Mar. 31, 2022 | Mar. 31, 2021 | |
Net income | $ 98,934 | $ 95,575 |
Other comprehensive income (loss), net of tax | ||
Change in pension and other postemployment benefit plan liability, net of tax of $(19) and $(91), respectively | 69 | 300 |
Other comprehensive income, net of tax | 69 | 300 |
Comprehensive income | $ 99,003 | $ 95,875 |
STATEMENTS OF COMPREHENSIVE I_2
STATEMENTS OF COMPREHENSIVE INCOME STATEMENTS OF COMPREHENSIVE INCOME Parenthetical - USD ($) $ in Thousands | 3 Months Ended | |
Mar. 31, 2022 | Mar. 31, 2021 | |
Pension and other postemployment benefit plans, tax | $ (19) | $ (91) |
BALANCE SHEETS
BALANCE SHEETS - USD ($) $ in Thousands | Mar. 31, 2022 | Dec. 31, 2021 |
Property, plant and equipment | ||
Property, plant and equipment | $ 7,365,981 | $ 7,274,268 |
Accumulated depreciation and amortization | 2,102,368 | 2,083,433 |
Net property, plant and equipment | 5,263,613 | 5,190,835 |
Current assets | ||
Cash and cash equivalents | 12,447 | 8,852 |
Accounts receivable, net | 494,696 | 341,756 |
Materials and supplies | 54,187 | 54,892 |
Natural gas in storage | 78,945 | 179,646 |
Regulatory assets | 1,600,034 | 1,611,676 |
Other current assets | 34,161 | 27,742 |
Total current assets | 2,274,470 | 2,224,564 |
Goodwill and other assets | ||
Regulatory assets | 651,931 | 724,862 |
Goodwill | 157,953 | 157,953 |
Other assets | 119,667 | 103,906 |
Total goodwill and other assets | 929,551 | 986,721 |
Total assets | 8,467,634 | 8,402,120 |
Equity and long-term debt | ||
Common stock, $0.01 par value: authorized 250,000,000 shares; issued and outstanding 54,089,817 shares at March 31, 2022; issued and outstanding 53,633,210 shares at December 31, 2021 | 541 | 536 |
Paid-in Capital | 1,824,771 | 1,790,362 |
Retained earnings | 630,536 | 565,161 |
Accumulated other comprehensive loss | (6,458) | (6,527) |
Total equity | 2,449,390 | 2,349,532 |
Long-term debt, excluding current maturities and net of issuance costs of $12,229 and $12,418, respectively | 2,283,620 | 3,683,378 |
Total equity and long-term debt | 4,733,010 | 6,032,910 |
Current liabilities | ||
Long-term Debt, Current Maturities | 1,400,011 | 11 |
Commercial Paper | 505,165 | 494,000 |
Accounts payable | 209,756 | 258,554 |
Accrued taxes other than income | 75,153 | 67,035 |
Regulatory Liability, Current | 32,822 | 8,090 |
Customer deposits | 61,105 | 62,454 |
Other current liabilities | 84,754 | 90,349 |
Total current liabilities | 2,368,766 | 980,493 |
Deferred credits and other liabilities | ||
Deferred income taxes | 698,765 | 695,284 |
Regulatory Liability, Noncurrent | 542,622 | 552,928 |
Employee benefit obligations | 28,468 | 35,226 |
Other deferred credits | 96,003 | 105,279 |
Liabilities, Other than Long-term Debt, Noncurrent | 1,365,858 | 1,388,717 |
Commitments and contingencies | ||
Total liabilities and equity | $ 8,467,634 | $ 8,402,120 |
BALANCE SHEETS BALANCE SHEETS P
BALANCE SHEETS BALANCE SHEETS Parenthetical - USD ($) $ in Thousands | Mar. 31, 2022 | Dec. 31, 2021 |
Common stock, shares authorized | 250,000,000 | 250,000,000 |
Common stock, shares issued | 54,089,817 | 53,633,210 |
Common stock, shares outstanding | 54,089,817 | 53,633,210 |
Debt issuance costs | $ 12,229 | $ 12,418 |
Liabilities, Other than Long-term Debt, Noncurrent | $ 1,365,858 | $ 1,388,717 |
Common stock, par value per share | $ 0.01 |
STATEMENTS OF CASH FLOWS
STATEMENTS OF CASH FLOWS - USD ($) $ in Thousands | 3 Months Ended | |
Mar. 31, 2022 | Mar. 31, 2021 | |
Operating activities | ||
Net income | $ 98,934 | $ 95,575 |
Adjustments to reconcile net income to net cash provided by operating activities: | ||
Depreciation and amortization | 57,137 | 52,266 |
Deferred income taxes | (6,849) | 18,567 |
Share-based compensation expense | 2,695 | 2,587 |
Provision for doubtful accounts | 1,338 | 3,754 |
Changes in assets and liabilities: | ||
Accounts receivable | (154,278) | 9,640 |
Materials and supplies | 705 | 1,619 |
Natural gas in storage | 100,701 | 49,625 |
Increase (Decrease) in Other Regulatory Assets | 9,554 | 9,885 |
Accounts payable | (56,863) | 87,202 |
Accrued taxes other than income | 8,118 | 2,059 |
Customer deposits | (1,349) | (10,787) |
IncreaseDecreaseInRegulatoryAssetsAndLiabilitiesCurrent | 36,374 | 20,466 |
IncreaseDecreaseInRegulatoryAssetsAndLiabilitiesNonCurrent | 66,002 | (1,946,526) |
Increase (Decrease) in Other Current Assets and Liabilities, Net | (12,438) | (20,698) |
Increase (Decrease) in Other Noncurrent Assets and Liabilities, Net | (23,037) | (14,729) |
Cash provided by operating activities | 107,636 | (1,659,265) |
Investing activities | ||
Capital expenditures | (113,307) | (99,093) |
Other | (608) | (2,351) |
Proceeds from Sale of Other Assets, Investing Activities | 549 | 241 |
Cash used in investing activities | (113,366) | (101,203) |
Financing activities | ||
Repayments of notes payable, net | 11,165 | 28,775 |
Proceeds from Issuance of Senior Long-term Debt | 0 | 2,498,895 |
Payments of Debt Issuance Costs | 0 | (35,110) |
Proceeds from Issuance of Common Stock | 34,468 | 0 |
Dividends paid | (33,285) | (30,882) |
Payment, Tax Withholding, Share-based Payment Arrangement | (3,023) | (4,292) |
Cash used in financing activities | 9,325 | 2,457,386 |
Change in cash and cash equivalents | 3,595 | 696,918 |
Cash and cash equivalents at beginning of period | 8,852 | 7,993 |
Cash and cash equivalents at end of period | $ 12,447 | $ 704,911 |
STATEMENT OF CHANGES IN EQUITY
STATEMENT OF CHANGES IN EQUITY - USD ($) $ in Thousands | Total | Common Stock [Member] | Paid-in Capital [Member] | Retained Earnings [Member] | Accumulated Other Comprehensive Income (Loss) [Member] |
Shares issued, beginning balance at Dec. 31, 2020 | 53,166,733 | ||||
Equity, beginning balance at Dec. 31, 2020 | $ 2,233,311 | $ 532 | $ 1,756,921 | $ 483,635 | $ (7,777) |
Net income | 95,575 | 0 | 0 | 95,575 | 0 |
Other comprehensive income | 300 | $ 0 | 0 | 0 | 300 |
Common stock issued, shares | 78,278 | ||||
Common stock issued, value | (1,705) | $ 0 | (1,705) | 0 | 0 |
Common stock dividends - $0.62 and $0.58 per share per quarter as of 2022 and 2021, respectively | (30,882) | $ 0 | 260 | (31,142) | 0 |
Shares issued, ending balance at Mar. 31, 2021 | 53,245,011 | ||||
Equity, ending balance at Mar. 31, 2021 | $ 2,296,599 | $ 532 | 1,755,476 | 548,068 | (7,477) |
Dividends declared per share of stock | $ 0.58 | ||||
Shares issued, beginning balance at Dec. 31, 2021 | 53,633,210 | 53,633,210 | |||
Equity, beginning balance at Dec. 31, 2021 | $ 2,349,532 | $ 536 | 1,790,362 | 565,161 | (6,527) |
Net income | 98,934 | 0 | 0 | 98,934 | 0 |
Other comprehensive income | 69 | $ 0 | 0 | 0 | 69 |
Common stock issued, shares | 456,607 | ||||
Common stock issued, value | 34,140 | $ 5 | 34,135 | 0 | 0 |
Common stock dividends - $0.62 and $0.58 per share per quarter as of 2022 and 2021, respectively | $ (33,285) | $ 0 | 274 | (33,559) | 0 |
Shares issued, ending balance at Mar. 31, 2022 | 54,089,817 | 54,089,817 | |||
Equity, ending balance at Mar. 31, 2022 | $ 2,449,390 | $ 541 | $ 1,824,771 | $ 630,536 | $ (6,458) |
Dividends declared per share of stock | $ 0.62 |
SUMMARY OF SIGNIFICANT ACCOUNTI
SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Notes) | 3 Months Ended |
Mar. 31, 2022 | |
Significant Accounting Policies [Line Items] | |
SIGNIFICANT ACCOUNTING POLICIES | 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 2021 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. Due to the seasonal nature of our business, the results of operations for the three months ended March 31, 2022, are not necessarily indicative of the results that may be expected for a 12-month period. We provide natural gas distribution services to our approximately 2.3 million customers through our divisions in Oklahoma, Kansas and Texas through Oklahoma Natural Gas, Kansas Gas Service and Texas Gas Service, respectively. We primarily serve residential, commercial and transportation customers in all three states. Use of Estimates - 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 amount 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 revenue and expense during the reporting period. Items that may be estimated include, but are not limited to, the economic useful life of assets, fair value of assets and liabilities, provisions for doubtful accounts receivable, unbilled revenues for natural gas delivered but for which meters have not been read, natural gas purchased but for which no invoice has been received, provision for income taxes, including any deferred income tax valuation allowances, the results of litigation and various other recorded or disclosed amounts. We evaluate these estimates on an ongoing basis using historical experience and other methods we consider reasonable based on the particular circumstances. Nevertheless, actual results may differ significantly from the estimates. Any effects on our financial position or results of operations from revisions to these estimates are recorded in the period when the facts that give rise to the revision become known. Segments - We operate in one reportable business segment: regulated public utilities that deliver natural gas primarily to residential, commercial and transportation customers. The accounting policies for our segment are the same as those described in Note 1 of our 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, 2022 and 2021, 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 process and asset removal costs decreased by approximately $8.1 million and $11.6 million for the three months ended March 31, 2022 and 2021, 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, 2022 and December 31, 2021, our allowance for doubtful accounts was $19.7 million and $18.7 million, respectively. Recently Issued Accounting Standards Update - In November 2021, the FASB issued ASU 2021-10, “Government Assistance (Topic 832): Disclosures by Business Entities about Government Assistance,” which will require disclosure about government assistance in the notes to the financial statements. The amendment requires annual disclosures about transactions with a government that are accounted for by applying a grant or contribution accounting model by analogy, including information about the nature of the transactions and the related accounting policy used to account for the transactions, the line items on the balance sheet and income statement that are affected by the transactions and the significant terms and conditions of the transactions, including commitments and contingencies. This guidance will apply to the anticipated securitizations in Oklahoma and Texas associated with Winter Storm Uri. The amendment became effective for us beginning January 1, 2022. As the guidance is related only to disclosures in the notes to the financial statements, we do not anticipate any impact on our financial position, results of operations or cash flows. In March 2020, the FASB issued ASU 2020-04, “Reference Rate Reform (Topic 848): Facilitation of the Effects of Reference Rate Reform on Financial Reporting,” which provides relief from the accounting analysis and impacts that may otherwise be required for modifications to agreements (e.g., loans, debt securities, derivatives, borrowings) necessitated by reference rate reform. It also provides optional expedients to enable companies to continue to apply hedge accounting to certain hedging relationships impacted by reference rate reform. In the first quarter 2020, we adopted this new guidance effective for contracts modified between March 12, 2020 and December 31, 2022. Our remaining $400 million of floating-rate senior notes due 2023 utilize LIBOR as the reference rate. If modified, we may elect the optional practical expedients to account for the modifications prospectively. Our adoption did not result in a material impact to our consolidated financial statements. |
REVENUE (Notes)
REVENUE (Notes) | 3 Months Ended |
Mar. 31, 2022 | |
Revenue from Contract with Customer | REVENUE The following table sets forth our revenues disaggregated by source for the periods indicated: Three Months Ended March 31, 2022 2021 (Thousands of dollars) Natural gas sales to customers $ 925,157 $ 583,794 Transportation revenues 36,316 36,202 Miscellaneous revenues 4,496 3,655 Total revenues from contracts with customers 965,969 623,651 Other revenues - natural gas sales related 2,346 (1,021) Other revenues 3,144 2,663 Total other revenues 5,490 1,642 Total revenues $ 971,459 $ 625,293 |
REGULATORY ASSETS AND LIABILITI
REGULATORY ASSETS AND LIABILITIES (Notes) | 3 Months Ended |
Mar. 31, 2022 | |
SCHEDULE OF REGULATED ASSETS AND LIABILITIES [Line Items] | |
Schedule of Regulatory Assets and Liabilities | REGULATORY ASSETS AND LIABILITIES The tables below present a summary of regulatory assets and liabilities, net of amortization, for the periods indicated: March 31, 2022 Current Noncurrent Total ( Thousands of dollars ) Winter weather event costs $ 1,539,868 $ 366,424 $ 1,906,292 Under-recovered purchased-gas costs 9,751 — 9,751 Pension and postemployment benefit costs 11,508 249,074 260,582 Reacquired debt costs 812 3,889 4,701 MGP remediation costs 98 29,816 29,914 Ad-valorem tax 8,192 — 8,192 WNA 11,440 — 11,440 Customer credit deferrals 17,177 — 17,177 Other 1,188 2,728 3,916 Total regulatory assets, net of amortization 1,600,034 651,931 2,251,965 Income tax rate changes — (542,622) (542,622) Over-recovered purchased-gas costs (32,822) — (32,822) Total regulatory liabilities (32,822) (542,622) (575,444) Net regulatory assets and liabilities $ 1,567,212 $ 109,309 $ 1,676,521 December 31, 2021 Current Noncurrent Total ( Thousands of dollars ) Winter weather event costs $ 1,536,054 $ 428,023 $ 1,964,077 Under-recovered purchased-gas costs 31,863 — 31,863 Pension and postemployment benefit costs 11,507 260,559 272,066 Reacquired debt costs 812 4,070 4,882 MGP remediation costs 98 29,841 29,939 Ad-valorem tax 8,561 — 8,561 WNA 10,044 — 10,044 Customer credit deferrals 10,685 — 10,685 Other 2,052 2,369 4,421 Total regulatory assets, net of amortization 1,611,676 724,862 2,336,538 Income tax rate changes — (552,928) (552,928) Over-recovered purchased-gas costs (8,090) — (8,090) Total regulatory liabilities (8,090) (552,928) (561,018) Net regulatory assets and liabilities $ 1,603,586 $ 171,934 $ 1,775,520 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 rider, base rates, or securitization, and we believe that we will be able to recover such costs consistent with our historical recoveries. 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 Kansas, Oklahoma, and Texas. During this time, the governors of Kansas, Oklahoma, 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 Kansas, Oklahoma, and Texas jurisdictions, which resulted in aggregated natural gas purchases for the month of February 2021 of approximately $2.1 billion. Beginning in the first quarter 2021, Oklahoma Natural Gas began deferring to a regulatory asset the extraordinary costs associated with this unprecedented winter weather event, including commodity costs, operational costs and carrying costs in accordance with an order issued by the OCC in March 2021. In April 2021, Oklahoma Natural Gas submitted an initial application requesting a financing order pursuant to newly enacted securitization legislation in Oklahoma. On January 25, 2022, the OCC approved the financing order that reflected the terms of a settlement agreement reached in November 2021, which includes an agreement that all extreme gas purchase and extraordinary costs incurred as a result of Winter Storm Uri were reasonable and prudent and a financing order should be issued to recover these costs through securitization over a 25-year period. Following the issuance of the financing order, no parties to our application appealed the financing order to the Oklahoma Supreme Court during the 30-day appeal period. The securitization legislation allows the ODFA 24 months to complete the process to issue the securitized bonds; however, the financing order requests the ODFA to issue bonds and provide the net proceeds to Oklahoma Natural Gas as soon as feasible, but no later than December 31, 2022. Pursuant to the securitization statute in Oklahoma, the Oklahoma Supreme Court must validate that the bond issuance proposed by the ODFA complies with the securitization statute and the laws of Oklahoma. The ODFA received a hearing before the Oklahoma Supreme Court on April 13, 2022, seeking validation of the bond issuance. If the Oklahoma Supreme Court issues a ruling that validates the bond issuance by the ODFA complies with the Oklahoma securitization statute and the laws of Oklahoma, the ODFA will continue the process to issue the securitized bonds associated with the Oklahoma Natural Gas financing order. At March 31, 2022, Oklahoma Natural Gas has deferred approximately $1.3 billion in extraordinary costs attributable to Winter Storm Uri. In March 2021, the KCC issued an order adopting the KCC staff’s recommendation to open company-specific dockets to accept each utility’s filing of financial impact compliance reports and permit the KCC staff to conduct a review of the utility’s compliance report and its actions during Winter Storm Uri. 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 October 2021, a nonunanimous settlement agreement was filed with the KCC to reach a resolution on these penalties. Prior to a hearing on the amended settlement in January 2022, all parties reached a unanimous settlement, which was filed with a motion requesting approval of the unanimous settlement. Under the terms of the unanimous settlement, the carrying charge on assessed penalties was reduced to two percent, consistent with the nonunanimous agreement in the financial docket. On March 3, 2022, the KCC issued an order approving the 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. Any amounts collected from these penalties will reduce the regulatory asset for the winter weather event up to $52.6 million. Through April 29, 2022, we have collected $47.5 million of these penalties. In July 2021, Kansas Gas Service submitted its financial plan to the KCC as required by the company-specific docket opened by the KCC in March 2021. The plan includes a proposal for the Company to issue securitized bonds to recover the extraordinary costs resulting from Winter Storm Uri from its customers over a period of either 5, 7, or 10 years. The KCC issued an order approving a unanimous settlement agreement on February 8, 2022, that allows Kansas Gas Service to recover extraordinary costs as of October 31, 2021, net of any penalties recovered from marketers and individually-balanced transportation customers, plus carrying costs calculated at two percent, by seeking a financing order from the KCC for the issuance of securitized utility tariff bonds. The extraordinary costs, other than purchased gas costs, will be trued-up and validated. On March 31, 2022, Kansas Gas Service submitted its application for a financing order to the KCC as contemplated by the unanimous settlement agreement, requesting approval to issue securitized bonds to recover extraordinary costs resulting from Winter Storm Uri and flexibility to recover the costs over 5, 7, 10 or 12 years. The KCC has until September 27, 2022, to review the application and issue a financing order if it deems the issuance of securitized bonds to be appropriate. If the KCC approves the financing order, we can begin the process to issue the securitized bonds. At March 31, 2022, Kansas Gas Service has deferred approximately $335.6 million in extraordinary costs, net of penalties billed, attributable to Winter Storm Uri. 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 on July 30, 2021, for an order authorizing the amount of extraordinary costs for recovery and other such specifications necessary for the issuance of securitized bonds. In November 2021, the RRC approved a unanimous settlement agreement between Texas Gas Service, the other natural gas utilities in Texas participating in the securitization process, the staff of the RRC and all intervenors. The settlement agreement provides that all costs incurred by Texas Gas Service to purchase natural gas during Winter Storm Uri were reasonable, necessary and prudently incurred. Texas Gas Service agreed to reduce its regulatory asset amount to be securitized by the amount of extraordinary costs attributable to the West Texas service area, which will be recovered through a separate surcharge over a three-year period. On February 8, 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 Texas Natural Gas Securitization Finance Corporation, a new independent public authority, for purposes of issuing the securitized bonds and has begun the process to issue the securitized bonds, which by statute must be issued no later than August 7, 2022. At March 31, 2022, Texas Gas Service has deferred approximately $248.3 million in extraordinary costs associated with Winter Storm Uri, which includes $50.7 million attributable to the West Texas service area. Pursuant to the approved settlement order, in January 2022, Texas Gas Service began collecting the extraordinary costs, including carrying costs, associated with Winter Storm Uri attributable to the West Texas service area from those customers. In accordance with these regulatory orders associated with the winter weather event, we have deferred approximately $1.9 billion in extraordinary costs for natural gas purchases, related financing and carrying costs and other operational costs. The amounts deferred at March 31, 2022, include invoiced costs for natural gas purchases that have not been paid as we work with our suppliers to resolve discrepancies in invoiced amounts. The amounts deferred may be adjusted as the differences are resolved. In addition, as a result of Winter Storm Uri, we were assessed penalties as a result of over- or under-deliveries of natural gas during periods that operational flow orders were imposed on us. Additionally, Kansas Gas Service assessed penalties under the modified penalty provisions of its tariff on marketers and individually-balanced transportation customers, or their agents, as approved by the KCC in March 2022. Amounts recorded reflect management’s best estimate of the amounts we may pay or receive and may be adjusted in future periods as the disposition of disputed invoices and the collectability of such penalties is determined. As these amounts are related to the extraordinary gas purchase costs associated with Winter Storm Uri, which are deferred, future adjustments to the amounts we have deferred 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 KCC. 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. 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 the customers’ bills to refund the over-collected revenue or bill the under-collected revenue over the subsequent 12 months. 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. See Note 12 for additional information regarding our regulatory assets for MGP remediation costs. |
CREDIT FACILITIES (Notes)
CREDIT FACILITIES (Notes) | 3 Months Ended |
Mar. 31, 2022 | |
Short-term Debt [Line Items] | |
Short-term Debt [Text Block] | CREDIT FACILITY AND SHORT-TERM DEBT On March 16, 2022, we entered into the first amendment to the second amended and restated ONE Gas Credit Agreement, which was previously amended and restated on March 16, 2021. The amendment extends the maturity date of the ONE Gas Credit Agreement to March 16, 2027, from March 16, 2026, and amends the ONE Gas Credit Agreement to provide that we may extend the maturity date, subject to the lenders’ consent, by one year two additional times. The amendment also changes the benchmark rate defined in the ONE Gas Credit Agreement to SOFR as administered by the Federal Reserve Bank of New York. All other material 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, 2022, our total debt-to-capital ratio was 63 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, 2022, 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. In June 2021, we increased the size of our commercial paper program to permit the issuance of commercial paper to fund short-term borrowing needs in an aggregate principal amount not to exceed $1.0 billion outstanding at any time. Prior to this increase, our commercial paper program permitted us to issue commercial paper in an aggregate principal amount not to exceed $700 million outstanding at any time. 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, 2022, we had $505.2 million of commercial paper outstanding. |
LONG-TERM DEBT (Notes)
LONG-TERM DEBT (Notes) | 3 Months Ended |
Mar. 31, 2022 | |
Long-term Debt, Unclassified [Abstract] | |
Long-term Debt [Text Block] | LONG-TERM DEBT Senior Notes - In March 2021, we issued $1.0 billion of 0.85 percent senior notes due March 2023, $700 million of 1.10 percent senior notes due March 2024, and $800 million of floating-rate senior notes due March 2023. The floating-rate senior notes bear interest at a rate equal to three-month LIBOR plus 61 basis points per year, reset quarterly for the applicable interest period (1.41 percent at March 31, 2022). The net proceeds from the issuance were used for payment of gas purchases and related costs resulting from Winter Storm Uri and general corporate purposes. In the event LIBOR is not available, and such circumstances are unlikely to be temporary, we or our designee may establish an alternative interest rate for our floating-rate senior notes due March 2023 by replacing LIBOR with one or more secured financing-based rates or another alternate benchmark rate. In September 2021, we called $400 million of the floating-rate senior notes due March 2023 at par, using a combination of cash on hand and commercial paper. We did not have the right to call these senior notes prior to September 11, 2021. As discussed in Note 3, the OCC and RRC have authorized financing orders and the KCC has authorized a financial plan for the recovery of the extraordinary costs incurred, including any future carrying costs, by Oklahoma Natural Gas, Texas Gas Service (excluding the West Texas service area) and Kansas Gas Service, respectively, through the issuance of securitized bonds. We anticipate securitized bonds will be issued in Oklahoma and Texas in 2022 and in Kansas in 2023. We expect to use these proceeds to call the outstanding senior notes due in March 2023 and March 2024, and use our commercial paper program to call any remaining 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. ONE Gas 2021 Term Loan Facility - In February 2021, we entered into the ONE Gas 2021 Term Loan Facility as part of the financing of our natural gas purchases in order to provide sufficient liquidity to satisfy our obligations as a result of Winter Storm Uri. The net proceeds of the March 2021 debt issuance reduced the commitments under the ONE Gas 2021 Term Loan Facility on a dollar-for-dollar basis, and as a result no commitments remained outstanding and the facility was terminated concurrently with the closing of the debt issuance. |
EQUITY (Notes)
EQUITY (Notes) | 3 Months Ended |
Mar. 31, 2022 | |
Class of Stock [Line Items] | |
Stockholders' Equity Note Disclosure [Text Block] | At-the-Market Equity Program - In February 2020, we initiated an at-the-market equity program by entering into an equity distribution agreement under which we may issue and sell shares of our common stock with an aggregate offering price up to $250 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). 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. 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. At March 31, 2022, we had $180.0 million of equity available for issuance under the program. Dividends Declared - In May 2022, we declared a dividend of $0.62 per share ($2.48 per share on an annualized basis) for shareholders of record as of May 16, 2022, payable on June 1, 2022. |
ACCUMULATED OTHER COMPREHENSIVE
ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS) (Notes) | 3 Months Ended |
Mar. 31, 2022 | |
Accumulated Other Comprehensive Income (Loss), Net of Tax [Abstract] | |
Comprehensive Income (Loss) Note | 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 2022 2021 of Income ( Thousands of dollars ) Pension and other postemployment benefit plan obligations (a) Amortization of net loss $ 8,201 $ 11,474 Amortization of unrecognized prior service cost (credit) 10 (70) 8,211 11,404 Regulatory adjustments (b) (8,123) (11,013) 88 391 Income before income taxes (19) (91) Income tax expense Total reclassifications for the period $ 69 $ 300 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. |
EARNINGS PER SHARE (Notes)
EARNINGS PER SHARE (Notes) | 3 Months Ended |
Mar. 31, 2022 | |
EARNINGS PER SHARE [Line Items] | |
Earnings Per Share [Text Block] | 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, but only to the extent these instruments dilute earnings per share. The following tables set forth the computation of basic and diluted EPS from continuing operations for the periods indicated: Three Months Ended March 31, 2022 Income Shares Per Share ( 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 Three Months Ended March 31, 2021 Income Shares Per Share ( Thousands, except per share amounts ) Basic EPS Calculation Net income available for common stock $ 95,575 53,372 $ 1.79 Diluted EPS Calculation Effect of dilutive securities — 143 Net income available for common stock and common stock equivalents $ 95,575 53,515 $ 1.79 |
EMPLOYEE BENEFIT PLANS (Notes)
EMPLOYEE BENEFIT PLANS (Notes) | 3 Months Ended |
Mar. 31, 2022 | |
Defined Benefit Plans and Other Postretirement Benefit Plans Disclosures [Abstract] | |
Employee Benefit Plans (Notes) | 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, 2022 2021 ( Thousands of dollars ) Components of net periodic benefit cost (credit) Service cost $ 3,094 $ 3,453 Interest cost 7,804 7,365 Expected return on assets (14,613) (15,596) Amortization of net loss 8,147 11,381 Net periodic benefit cost $ 4,432 $ 6,603 Other Postemployment Benefits Three Months Ended March 31, 2022 2021 ( Thousands of dollars ) Components of net periodic benefit cost (credit) Service cost $ 318 $ 397 Interest cost 1,612 1,563 Expected return on assets (3,295) (4,202) Amortization of unrecognized prior service cost (credit) 10 (70) Amortization of net loss 54 93 Net periodic benefit cost (credit) $ (1,301) $ (2,219) 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. Regulatory deferrals related to net periodic benefit cost were not material for the three months ended March 31, 2022 and 2021, respectively. We continue to 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 $5.8 million and $6.1 million as of March 31, 2022 and December 31, 2021, respectively. See Note 3 of the Notes to Consolidated Financial Statements in this Quarterly Report for additional information. |
INCOME TAXES (Notes)
INCOME TAXES (Notes) | 3 Months Ended |
Mar. 31, 2022 | |
Income Tax Disclosure [Abstract] | |
Income Tax Disclosure | 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. As of March 31, 2022, 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 2018. In May 2021, a bill amending the Oklahoma state income tax code was signed into law that reduced the state income tax rate to four percent from six percent beginning January 1, 2022. As a result of the enactment of this legislation, we remeasured our ADIT. As a regulated entity, the reduction in ADIT of $29.3 million w as recorded as a regulatory liability. The impact of the change in the state income tax rate on Oklahoma Natural Gas’ rates, as wells the timing and am ount of the impact on the annual crediting mechanism for the EDIT regulatory liability, will be addressed during the processing of the March 15, 2022 PBRC filing. Income tax expense reflects credits for the amortization of the regulatory liability associated with EDIT that was returned to customers of $7.9 million and $8.1 million for the three months ended March 31, 2022 and 2021, respectively. |
OTHER INCOME AND OTHER EXPENSE
OTHER INCOME AND OTHER EXPENSE (Notes) | 3 Months Ended |
Mar. 31, 2022 | |
Other Income and Other Expense Disclosure [Text Block] | 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, 2022 2021 ( Thousands of dollars ) Net periodic benefit cost other than service cost $ (588) $ (770) Earnings (losses) on investments associated with nonqualified employee benefit plans (2,833) 616 Other, net (724) (251) Total other expense, net $ (4,145) $ (405) |
COMMITMENTS AND CONTINGENCIES (
COMMITMENTS AND CONTINGENCIES (Notes) | 3 Months Ended |
Mar. 31, 2022 | |
Commitments and Contingencies [Line Items] | |
COMMITMENTS AND CONTINGENCIES | COMMITMENTS AND CONTINGENCIES COVID-19 - Throughout the COVID-19 pandemic, we have continued to provide essential services to our customers. We have implemented a comprehensive set of policies, procedures and guidelines to protect the safety of our employees, customers and communities. See Note 3 for more information regarding the effects of COVID-19 on us. 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, 2022 and 2021. 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, 2022, we have deferred $30.0 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 and anticipates that filing will occur in 2023. 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. A remediation plan concerning this site was submitted to the KDHE in 2020 and the KDHE has provided comments that we are addressing. We are also working on a remediation plan for an additional site that we expect to submit to the KDHE in 2022. 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. On April 14, 2022, we submitted a remediation work plan to address the areas impacted to the TCEQ. At March 31, 2022, 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, 2022 and 2021. The reserve for remediation of our MGP sites was $20.3 million and $23.0 million at March 31, 2022 and December 31, 2021, respectively. Environmental issues may exist with respect to MGP sites that are unknown to us. Accordingly, future costs are dependent on the final determination and regulatory approval of any remedial actions, the complexity of the site, level of remediation required, changing technology and governmental regulations, and to the extent not recovered by insurance or recoverable in rates from our customers, could be material to our financial condition, results of operations or cash flows. We are subject to environmental regulation by federal, state and local authorities. Due to the inherent uncertainties surrounding the development of federal and state environmental laws and regulations, we cannot determine with specificity the impact such laws and regulations may have on our existing and future facilities. With the trend toward stricter standards, greater regulation and more extensive permit requirements for the types of assets operated by us, our environmental expenditures could increase in the future, and such expenditures may not be fully recovered by insurance or recoverable in rates from our customers, and those costs may adversely affect our financial condition, results of operations and cash flows. 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 regulating pipeline safety, PHMSA promulgates various regulations. For example, in April 2016, PHMSA published a NPRM, the Safety of Gas Transmission & Gathering Lines Rule, in the Federal Register to revise pipeline safety regulations applicable to the safety of onshore natural gas transmission and gathering pipelines. Proposals included changes to pipeline integrity management requirements and other safety-related requirements. Subsequently, PHMSA announced they would split this NPRM into three separate final rulemakings: • the first final rule addresses the legislative mandates from the Pipeline Safety, Regulatory Certainty and Job Creation Act and is called the Safety of Gas Transmission Pipelines: MAOP Reconfirmation, Expansion of Assessment Requirements, and Other Related Amendments; • the second final rule will be called the Safety of Gas Transmission Pipelines: Repair Criteria, Integrity Management Improvements, Cathodic Protection, Management of Change, and Other Related Amendments and will cover all remaining elements of the NPRM (except for gas gathering pipelines); and • the third final rule will be called the Safety of Gas Gathering Pipelines and will address gas gathering pipelines. On October 1, 2019, PHMSA published the first of the three final rules referenced above, which addressed the 2011 congressional mandates. This final rule expands integrity management principles beyond HCAs and requires operators to collect traceable, verifiable and complete records moving forward, retain existing and new records for the life of the pipeline, and reconfirm pipeline MAOP in populated areas. The final rule also outlines methods for reconfirming a pipeline’s MAOP within 15 years. The first final rule became effective July 1, 2020. Our estimated capital and operating expenditures associated with compliance with the first final rulemaking were not material. PHMSA has not yet issued the second final rule. The potential capital and operating expenditures associated with compliance with this rule are currently being evaluated and could be significant depending on the final regulation. We do not expect to be impacted by the third final rule, as we do not own gas gathering pipelines. Separately, as part of the Consolidated Appropriations Act, 2021, the PIPES Act of 2020 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. |
DERIVATIVE FINANCIAL INSTRUMENT
DERIVATIVE FINANCIAL INSTRUMENTS AND FAIR VALUE MEASUREMENTS (Notes) | 3 Months Ended |
Mar. 31, 2022 | |
Fair Value Disclosures [Abstract] | |
Fair Value Disclosures | 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 and - 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 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, 2022, we had no purchased natural gas call options. At December 31, 2021, we held purchased natural gas call options for the heating season ended March 2022, with total notional amounts of 13.2 Bcf, for which we paid premiums of $9.5 million, and which had a fair value of $2.3 million. 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, accounts receivable and accounts payable is equal to book value, due to the short-term nature of these items. Our cash and cash equivalents are comprised of bank and money market accounts and are classified as Level 1. At March 31, 2022 and December 31, 2021, our other current and noncurrent assets include $7.0 million and $6.9 million of corporate bonds, respectively, and $3.2 million and $3.5 million of United States treasury notes, respectively. The fair value of corporate bonds and United States treasury notes approximate carrying value, and are classified as Level 2 and Level 1, respectively. |
SUMMARY OF SIGNIFICANT ACCOUN_2
SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Policies) | 3 Months Ended |
Mar. 31, 2022 | |
Significant Accounting Policies [Line Items] | |
Use of Estimates | Use of Estimates - 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 amount 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 revenue and expense during the reporting period. Items that may be estimated include, but are not limited to, the economic useful life of assets, fair value of assets and liabilities, provisions for doubtful accounts receivable, unbilled revenues for natural gas delivered but for which meters have not been read, natural gas purchased but for which no invoice has been received, provision for income taxes, including any deferred income tax valuation allowances, the results of litigation and various other recorded or disclosed amounts. We evaluate these estimates on an ongoing basis using historical experience and other methods we consider reasonable based on the particular circumstances. Nevertheless, actual results may differ significantly from the estimates. Any effects on our financial position or results of operations from revisions to these estimates are recorded in the period when the facts that give rise to the revision become known. |
Segments | Segments - We operate in one reportable business segment: regulated public utilities that deliver natural gas primarily to residential, commercial and transportation customers. The accounting policies for our segment are the same as those described in Note 1 of our 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, 2022 and 2021, we had no single external customer from which we received 10 percent or more of our gross revenues. |
Receivables, Trade and Other Accounts Receivable, Allowance for Doubtful Accounts, Policy [Policy Text Block] | 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, 2022 and December 31, 2021, our allowance for doubtful accounts was $19.7 million and $18.7 million, respectively. |
Recently Issued Accounting Standards Update | Recently Issued Accounting Standards Update - In November 2021, the FASB issued ASU 2021-10, “Government Assistance (Topic 832): Disclosures by Business Entities about Government Assistance,” which will require disclosure about government assistance in the notes to the financial statements. The amendment requires annual disclosures about transactions with a government that are accounted for by applying a grant or contribution accounting model by analogy, including information about the nature of the transactions and the related accounting policy used to account for the transactions, the line items on the balance sheet and income statement that are affected by the transactions and the significant terms and conditions of the transactions, including commitments and contingencies. This guidance will apply to the anticipated securitizations in Oklahoma and Texas associated with Winter Storm Uri. The amendment became effective for us beginning January 1, 2022. As the guidance is related only to disclosures in the notes to the financial statements, we do not anticipate any impact on our financial position, results of operations or cash flows. In March 2020, the FASB issued ASU 2020-04, “Reference Rate Reform (Topic 848): Facilitation of the Effects of Reference Rate Reform on Financial Reporting,” which provides relief from the accounting analysis and impacts that may otherwise be required for modifications to agreements (e.g., loans, debt securities, derivatives, borrowings) necessitated by reference rate reform. It also provides optional expedients to enable companies to continue to apply hedge accounting to certain hedging relationships impacted by reference rate reform. In the first quarter 2020, we adopted this new guidance effective for contracts modified between March 12, 2020 and December 31, 2022. Our remaining $400 million of floating-rate senior notes due 2023 utilize LIBOR as the reference rate. If modified, we may elect the optional practical expedients to account for the modifications prospectively. Our adoption did not result in a material impact to our consolidated financial statements. |
DERIVATIVE FINANCIAL INSTRUME_2
DERIVATIVE FINANCIAL INSTRUMENTS AND FAIR VALUE MEASUREMENTS DERIVATIVE FINANCIAL INSTRUMENTS AND FAIR VALUE MEASUREMENTS (Policies) | 3 Months Ended |
Mar. 31, 2022 | |
Accounting Policies [Abstract] | |
Derivatives | 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 and - 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 Measurement | 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 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. |
REVENUE (Tables)
REVENUE (Tables) | 3 Months Ended |
Mar. 31, 2022 | |
Revenues Disaggregated by Source [Table] | The following table sets forth our revenues disaggregated by source for the periods indicated: Three Months Ended March 31, 2022 2021 (Thousands of dollars) Natural gas sales to customers $ 925,157 $ 583,794 Transportation revenues 36,316 36,202 Miscellaneous revenues 4,496 3,655 Total revenues from contracts with customers 965,969 623,651 Other revenues - natural gas sales related 2,346 (1,021) Other revenues 3,144 2,663 Total other revenues 5,490 1,642 Total revenues $ 971,459 $ 625,293 |
REGULATORY ASSETS AND LIABILI_2
REGULATORY ASSETS AND LIABILITIES (Tables) | 3 Months Ended |
Mar. 31, 2022 | |
SCHEDULE OF REGULATED ASSETS AND LIABILITIES [Line Items] | |
SCHEDULE OF REGULATED ASSETS AND LIABILITIES | The tables below present a summary of regulatory assets and liabilities, net of amortization, for the periods indicated: March 31, 2022 Current Noncurrent Total ( Thousands of dollars ) Winter weather event costs $ 1,539,868 $ 366,424 $ 1,906,292 Under-recovered purchased-gas costs 9,751 — 9,751 Pension and postemployment benefit costs 11,508 249,074 260,582 Reacquired debt costs 812 3,889 4,701 MGP remediation costs 98 29,816 29,914 Ad-valorem tax 8,192 — 8,192 WNA 11,440 — 11,440 Customer credit deferrals 17,177 — 17,177 Other 1,188 2,728 3,916 Total regulatory assets, net of amortization 1,600,034 651,931 2,251,965 Income tax rate changes — (542,622) (542,622) Over-recovered purchased-gas costs (32,822) — (32,822) Total regulatory liabilities (32,822) (542,622) (575,444) Net regulatory assets and liabilities $ 1,567,212 $ 109,309 $ 1,676,521 December 31, 2021 Current Noncurrent Total ( Thousands of dollars ) Winter weather event costs $ 1,536,054 $ 428,023 $ 1,964,077 Under-recovered purchased-gas costs 31,863 — 31,863 Pension and postemployment benefit costs 11,507 260,559 272,066 Reacquired debt costs 812 4,070 4,882 MGP remediation costs 98 29,841 29,939 Ad-valorem tax 8,561 — 8,561 WNA 10,044 — 10,044 Customer credit deferrals 10,685 — 10,685 Other 2,052 2,369 4,421 Total regulatory assets, net of amortization 1,611,676 724,862 2,336,538 Income tax rate changes — (552,928) (552,928) Over-recovered purchased-gas costs (8,090) — (8,090) Total regulatory liabilities (8,090) (552,928) (561,018) Net regulatory assets and liabilities $ 1,603,586 $ 171,934 $ 1,775,520 |
ACCUMULATED OTHER COMPREHENSI_2
ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS) (Tables) | 3 Months Ended |
Mar. 31, 2022 | |
Accumulated Other Comprehensive Income (Loss) [Line Items] | |
Reclassification out of Accumulated Other Comprehensive Income [Table Text Block] | 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 2022 2021 of Income ( Thousands of dollars ) Pension and other postemployment benefit plan obligations (a) Amortization of net loss $ 8,201 $ 11,474 Amortization of unrecognized prior service cost (credit) 10 (70) 8,211 11,404 Regulatory adjustments (b) (8,123) (11,013) 88 391 Income before income taxes (19) (91) Income tax expense Total reclassifications for the period $ 69 $ 300 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. |
EARNINGS PER SHARE (Tables)
EARNINGS PER SHARE (Tables) | 3 Months Ended |
Mar. 31, 2022 | |
EARNINGS PER SHARE [Line Items] | |
Schedule of Earnings Per Share, Basic and Diluted [Table Text Block] | The following tables set forth the computation of basic and diluted EPS from continuing operations for the periods indicated: Three Months Ended March 31, 2022 Income Shares Per Share ( 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 Three Months Ended March 31, 2021 Income Shares Per Share ( Thousands, except per share amounts ) Basic EPS Calculation Net income available for common stock $ 95,575 53,372 $ 1.79 Diluted EPS Calculation Effect of dilutive securities — 143 Net income available for common stock and common stock equivalents $ 95,575 53,515 $ 1.79 |
EMPLOYEE BENEFIT PLANS (Tables)
EMPLOYEE BENEFIT PLANS (Tables) | 3 Months Ended |
Mar. 31, 2022 | |
Employee Benefit Plans [Line Items] | |
Schedule of Net Benefit Costs [Table Text Block] | 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, 2022 2021 ( Thousands of dollars ) Components of net periodic benefit cost (credit) Service cost $ 3,094 $ 3,453 Interest cost 7,804 7,365 Expected return on assets (14,613) (15,596) Amortization of net loss 8,147 11,381 Net periodic benefit cost $ 4,432 $ 6,603 Other Postemployment Benefits Three Months Ended March 31, 2022 2021 ( Thousands of dollars ) Components of net periodic benefit cost (credit) Service cost $ 318 $ 397 Interest cost 1,612 1,563 Expected return on assets (3,295) (4,202) Amortization of unrecognized prior service cost (credit) 10 (70) Amortization of net loss 54 93 Net periodic benefit cost (credit) $ (1,301) $ (2,219) |
OTHER INCOME AND OTHER EXPENS_2
OTHER INCOME AND OTHER EXPENSE (Tables) | 3 Months Ended |
Mar. 31, 2022 | |
Other Income and Other Expense Disclosure | The following table sets forth the components of other income and other expense for the periods indicated: Three Months Ended March 31, 2022 2021 ( Thousands of dollars ) Net periodic benefit cost other than service cost $ (588) $ (770) Earnings (losses) on investments associated with nonqualified employee benefit plans (2,833) 616 Other, net (724) (251) Total other expense, net $ (4,145) $ (405) |
SUMMARY OF SIGNIFICANT ACCOUN_3
SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Details) number in Millions, $ in Millions | 3 Months Ended | ||
Mar. 31, 2022USD ($) | Mar. 31, 2021USD ($) | Dec. 31, 2021USD ($) | |
Significant Accounting Policies [Line Items] | |||
Number of natural gas distribution services customers | 2.3 | ||
Segment Reporting, Disclosure of Major Customers | no | — | |
Capital Expenditures Incurred but Not yet Paid | $ 8.1 | $ 11.6 | |
Allowance for Doubtful Accounts, Premiums and Other Receivables | $ 19.7 | $ 18.7 |
REVENUE (Details)
REVENUE (Details) - USD ($) $ in Thousands | 3 Months Ended | ||
Mar. 31, 2022 | Mar. 31, 2021 | Dec. 31, 2021 | |
Regulated Operating Revenue, Gas | $ 965,969 | $ 623,651 | |
Regulated Operating Revenue, Other | 5,490 | 1,642 | |
Regulated Operating Revenue | 971,459 | 625,293 | |
Unbilled Receivables, Current | 148,000 | $ 183,200 | |
Natural gas sales to customers [Member] | |||
Regulated Operating Revenue, Gas | 925,157 | 583,794 | |
Transportation revenues [Member] | |||
Regulated Operating Revenue, Gas | 36,316 | 36,202 | |
Miscellaneous revenues [Member] | |||
Regulated Operating Revenue, Gas | 4,496 | 3,655 | |
Other revenues - natural gas sales related [Member] | |||
Regulated Operating Revenue, Other | 2,346 | (1,021) | |
Other revenues [Member] | |||
Regulated Operating Revenue, Other | $ 3,144 | $ 2,663 |
REGULATORY ASSETS AND LIABILI_3
REGULATORY ASSETS AND LIABILITIES (Details) - USD ($) $ in Thousands | 3 Months Ended | 4 Months Ended | |||
Mar. 31, 2022 | Mar. 31, 2021 | Apr. 29, 2022 | Dec. 31, 2021 | Feb. 28, 2021 | |
SCHEDULE OF REGULATED ASSETS AND LIABILITIES [Line Items] | |||||
Regulatory Assets, Current | $ 1,600,034 | $ 1,611,676 | |||
Regulatory Assets, Noncurrent | 651,931 | 724,862 | |||
Regulatory Assets | 2,251,965 | 2,336,538 | |||
Regulatory Liability, Current | (32,822) | (8,090) | |||
Regulatory Liability, Noncurrent | (542,622) | (552,928) | |||
Regulatory Liabilities | (575,444) | (561,018) | |||
Net regulatory assets (liabilities), current | 1,567,212 | 1,603,586 | |||
Net regulatory assets (liabilities), noncurrent | 109,309 | 171,934 | |||
Net Regulatory Assets | 1,676,521 | 1,775,520 | |||
February 2021 Natural Gas Purchases | $ 2,100,000 | ||||
ONG Deferred Extraordinary Costs from 2021 Winter Storm Uri | 1,300,000 | ||||
Maximum amount the regulatory asset for the winter storm can be reduced by for collections of penalties assessed on marketers and individually balanced transportation customers | 52,600 | ||||
Collections of penalties assessed on marketers and individually balanced transportation customers as a result of Winter Storm Uri | $ 47,500 | ||||
KGS Deferred Extraordinary Costs from 2021 Winter Storm Uri | 335,600 | ||||
TGS Deferred Extraordinary Costs from 2021 Winter Storm Uri | 248,300 | ||||
Deferred Extraordinary Costs from 2021 Winter Storm Uri | 1,900,000 | ||||
Amortization of Rate Deferral | 4,400 | $ 2,900 | |||
North Texas Service Area | |||||
SCHEDULE OF REGULATED ASSETS AND LIABILITIES [Line Items] | |||||
TGS Deferred Extraordinary Costs from 2021 Winter Storm Uri | 50,700 | ||||
Income tax rate changes [Member] [Domain] | |||||
SCHEDULE OF REGULATED ASSETS AND LIABILITIES [Line Items] | |||||
Regulatory Liability, Current | 0 | 0 | |||
Regulatory Liability, Noncurrent | (542,622) | (552,928) | |||
Regulatory Liabilities | (542,622) | (552,928) | |||
Over-recovered purchased-gas costs [Member] | |||||
SCHEDULE OF REGULATED ASSETS AND LIABILITIES [Line Items] | |||||
Regulatory Liability, Current | (32,822) | (8,090) | |||
Regulatory Liability, Noncurrent | 0 | 0 | |||
Regulatory Liabilities | (32,822) | (8,090) | |||
Winter weather event costs | |||||
SCHEDULE OF REGULATED ASSETS AND LIABILITIES [Line Items] | |||||
Regulatory Assets, Current | 1,539,868 | 1,536,054 | |||
Regulatory Assets, Noncurrent | 366,424 | 428,023 | |||
Regulatory Assets | 1,906,292 | 1,964,077 | |||
Under-recovered purchased-gas costs [Member] | |||||
SCHEDULE OF REGULATED ASSETS AND LIABILITIES [Line Items] | |||||
Regulatory Assets, Current | 9,751 | 31,863 | |||
Regulatory Assets, Noncurrent | 0 | 0 | |||
Regulatory Assets | 9,751 | 31,863 | |||
Pension and postretirement benefit costs [Member] | |||||
SCHEDULE OF REGULATED ASSETS AND LIABILITIES [Line Items] | |||||
Regulatory Assets, Current | 11,508 | 11,507 | |||
Regulatory Assets, Noncurrent | 249,074 | 260,559 | |||
Regulatory Assets | 260,582 | 272,066 | |||
Reacquired debt costs [Member] | |||||
SCHEDULE OF REGULATED ASSETS AND LIABILITIES [Line Items] | |||||
Regulatory Assets, Current | 812 | 812 | |||
Regulatory Assets, Noncurrent | 3,889 | 4,070 | |||
Regulatory Assets | 4,701 | 4,882 | |||
MGP Costs [Member] [Member] | |||||
SCHEDULE OF REGULATED ASSETS AND LIABILITIES [Line Items] | |||||
Regulatory Assets, Current | 98 | 98 | |||
Regulatory Assets, Noncurrent | 29,816 | 29,841 | |||
Regulatory Assets | 29,914 | 29,939 | |||
Ad valorem tax [Member] | |||||
SCHEDULE OF REGULATED ASSETS AND LIABILITIES [Line Items] | |||||
Regulatory Assets, Current | 8,192 | 8,561 | |||
Regulatory Assets, Noncurrent | 0 | 0 | |||
Regulatory Assets | 8,192 | 8,561 | |||
Weather normalization [Member] | |||||
SCHEDULE OF REGULATED ASSETS AND LIABILITIES [Line Items] | |||||
Regulatory Assets, Current | 11,440 | 10,044 | |||
Regulatory Assets, Noncurrent | 0 | 0 | |||
Regulatory Assets | 11,440 | 10,044 | |||
Customer credit deferrals | |||||
SCHEDULE OF REGULATED ASSETS AND LIABILITIES [Line Items] | |||||
Regulatory Assets, Current | 17,177 | 10,685 | |||
Regulatory Assets, Noncurrent | 0 | 0 | |||
Regulatory Assets | 17,177 | 10,685 | |||
Other regulatory assets [Member] | |||||
SCHEDULE OF REGULATED ASSETS AND LIABILITIES [Line Items] | |||||
Regulatory Assets, Current | 1,188 | 2,052 | |||
Regulatory Assets, Noncurrent | 2,728 | 2,369 | |||
Regulatory Assets | $ 3,916 | $ 4,421 |
CREDIT FACILITIES (Details)
CREDIT FACILITIES (Details) $ in Thousands | Mar. 31, 2022USD ($) | Dec. 31, 2021USD ($) |
Short-term Debt [Line Items] | ||
Line of Credit Facility, Maximum Borrowing Capacity | $ 1,000,000 | |
Line of Credit Facility Sublimit | 20,000 | |
Bridge Loan | 60,000 | |
Line of Credit Facility Option to Increase Borrowing Capacity | $ 500,000 | |
Ratio of Indebtedness to Net Capital | 0.63 | |
Letters of Credit Outstanding, Amount | $ 1,200 | |
Line of Credit Facility, Remaining Borrowing Capacity | 998,800 | |
Commercial paper maximum borrowing capacity | 1,000,000 | |
Commercial Paper | $ 505,165 | $ 494,000 |
Approved Debt to Capital Ratio After December 31, 2021 | 0.70 | |
Maximum borrowing capacity under the commercial paper program prior to June 2021 | $ 700,000 |
LONG-TERM DEBT (Details)
LONG-TERM DEBT (Details) - USD ($) $ in Millions | Sep. 21, 2021 | Mar. 31, 2022 |
Debt Instrument [Line Items] | ||
Debt Instrument, Covenant Description | 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. | |
OGS Note Payable Due 2023 | ||
Debt Instrument [Line Items] | ||
Long-term Debt, Gross | $ 800 | |
Long-term Debt, Percentage Bearing Variable Interest, Percentage Rate | 1.41% | |
Debt Instrument, Interest Rate Terms | The floating-rate senior notes bear interest at a rate equal to three-month LIBOR plus 61 basis points per year, reset quarterly for the applicable interest period (1.41 percent at March 31, 2022). | |
Debt Instrument, Basis Spread on Variable Rate | 0.61% | |
Proceeds from (Repayments of) Other Long-term Debt | $ 400 | |
Debt Instrument, Covenant Description | 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. | |
OGS Note Payable Due 2024 at 1.10 Percent | ||
Debt Instrument [Line Items] | ||
Long-term Debt, Gross | $ 700 | |
Debt Instrument, Interest Rate, Stated Percentage | 1.10% | |
Debt Instrument, Covenant Description | 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. | |
Notes Payable at 0.85% Due 2023 | ||
Debt Instrument [Line Items] | ||
Long-term Debt, Gross | $ 1,000 | |
Debt Instrument, Interest Rate, Stated Percentage | 0.85% | |
Debt Instrument, Covenant Description | 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. | |
Note Payable Due 2030 [Member] | ||
Debt Instrument [Line Items] | ||
Debt Instrument, Covenant Description | The indenture governing our Senior Notes includes an event of default upon the acceleration of other indebtedness of $100 million or more. Such events of default would entitle the trustee or the holders of 25 percent in aggregate principal amount of the outstanding Senior Notes to declare those senior notes immediately due and payable in full. |
EQUITY (Details)
EQUITY (Details) - USD ($) | 3 Months Ended | ||
Jun. 30, 2022 | Mar. 31, 2022 | Mar. 31, 2021 | |
At-the-Market Equity Program, Aggregate Offering Price Limit | $ 250,000,000 | ||
At-the-Market Equity Program, Shares Issued | 403,792 | ||
At-the-Market Equity Program, Gross Proceeds | 35,000,000 | ||
AtTheMarketEquityProgramIssuanceCosts | 34,700,000 | ||
At-the-Market Equity Program, Equity Available for Issuance | $ 180,000,000 | ||
Common Stock, Dividends, Per Share, Declared | $ 0.62 | $ 0.58 | |
Subsequent Event [Member] | |||
Common Stock, Dividends, Per Share, Declared | $ 0.62 | ||
Common Stock, Dividends, Declared, Annualized Basis | $ 2.48 | ||
Dividends Payable, Date of Record | May 16, 2022 | ||
Dividends Payable, Date to be Paid | Jun. 1, 2022 |
ACCUMULATED OTHER COMPREHENSI_3
ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS) (Details) - USD ($) $ in Thousands | 3 Months Ended | |
Mar. 31, 2022 | Mar. 31, 2021 | |
Accumulated Other Comprehensive Income (Loss) [Line Items] | ||
Amortization of net loss | $ 8,201 | $ 11,474 |
Amortization of unrecognized prior service cost | 10 | (70) |
Reclassification adjustment, before tax and regulatory adjustments | 8,211 | 11,404 |
Regulatory adjustments | (8,123) | (11,013) |
Reclassification adjustment, before tax | 88 | 391 |
Reclassification adjustment, Tax | (19) | (91) |
Reclassification adjustment, net of tax | $ 69 | $ 300 |
EARNINGS PER SHARE (Details)
EARNINGS PER SHARE (Details) - USD ($) $ / shares in Units, shares in Thousands, $ in Thousands | 3 Months Ended | |
Mar. 31, 2022 | Mar. 31, 2021 | |
Basic EPS Calculation | ||
Net income available for common stock | $ 98,934 | $ 95,575 |
Weighted Average Number of Shares Outstanding, Basic | 53,922 | 53,372 |
Earnings Per Share, Basic | $ 1.83 | $ 1.79 |
Diluted EPS Calculation | ||
Net income available for common stock | $ 98,934 | $ 95,575 |
Effect of dilutive securities on shares | 108 | 143 |
Weighted Average Number of Shares Outstanding, Diluted | 54,030 | 53,515 |
Earnings Per Share, Diluted | $ 1.83 | $ 1.79 |
Net Income (Loss) Available to Common Stockholders, Diluted | $ 98,934 | $ 95,575 |
EMPLOYEE BENEFIT PLANS (Details
EMPLOYEE BENEFIT PLANS (Details) - USD ($) $ in Thousands | 3 Months Ended | ||
Mar. 31, 2022 | Mar. 31, 2021 | Dec. 31, 2021 | |
Employee Benefit Plans [Line Items] | |||
Capitalized non-service cost components as a regulatory asset | $ 5,800 | $ 6,100 | |
Components of net periodic benefit cost: | |||
Amortization of unrecognized prior service cost | (10) | $ 70 | |
Amortization of net loss | (8,201) | (11,474) | |
ONE Gas Pension Plans [Member] | |||
Components of net periodic benefit cost: | |||
Service cost | 3,094 | 3,453 | |
Interest cost | 7,804 | 7,365 | |
Expected return on assets | (14,613) | (15,596) | |
Amortization of net loss | 8,147 | 11,381 | |
Net periodic benefit cost | 4,432 | 6,603 | |
ONE Gas Postretirement Benefit Plans [Member] | |||
Components of net periodic benefit cost: | |||
Service cost | 318 | 397 | |
Interest cost | 1,612 | 1,563 | |
Expected return on assets | (3,295) | (4,202) | |
Amortization of unrecognized prior service cost | 10 | (70) | |
Amortization of net loss | 54 | 93 | |
Net periodic benefit cost | $ (1,301) | $ (2,219) |
INCOME TAXES (Details)
INCOME TAXES (Details) - USD ($) $ in Millions | 3 Months Ended | |
Mar. 31, 2022 | Mar. 31, 2021 | |
Income Tax Disclosure [Abstract] | ||
Reduction in ADIT recorded as an EDIT regulatory liability associated with reduction of Oklahoma state income tax | $ 29.3 | |
Reduction in income tax expense for the amortization of the regulatory liability associated with excess ADIT that was returned to customers | $ 7.9 | $ 8.1 |
OTHER INCOME AND OTHER EXPENS_3
OTHER INCOME AND OTHER EXPENSE (Details) - USD ($) $ in Thousands | 3 Months Ended | |
Mar. 31, 2022 | Mar. 31, 2021 | |
Other, net | $ (4,145) | $ (405) |
Net periodic cost other than service cost | (588) | (770) |
Earnings (losses) on investments associated with nonqualified employee benefit plans | (2,833) | 616 |
Other, net | $ (724) | $ (251) |
COMMITMENTS AND CONTINGENCIES_2
COMMITMENTS AND CONTINGENCIES (Details) $ in Millions | Mar. 31, 2022USD ($) | Dec. 31, 2021USD ($) |
Commitments and Contingencies [Line Items] | ||
Number Of Former Manufactured Gas Sites Where We Own Or Retain Legal Responsibility For Environmental Conditions | 12 | |
Number of sites where regulatory closure has been achieved | 5 | |
Number of sites with ongoing groundwater monitoring | 7 | |
Accrual for Environmental Loss Contingencies | $ 20.3 | $ 23 |
Deferred MGP Costs, Maximum | 15 | |
Regulatory Asset for Costs Associated with Manufactured Gas Sites | $ 30 |
DERIVATIVE FINANCIAL INSTRUME_3
DERIVATIVE FINANCIAL INSTRUMENTS AND FAIR VALUE MEASUREMENTS (Details) | 3 Months Ended | |
Mar. 31, 2022USD ($) | Dec. 31, 2021USD ($)Bcf | |
Fair Value, Assets and Liabilities Measured on Recurring Basis [Line Items] | ||
Derivative, Nonmonetary Notional Amount | Bcf | 13.2 | |
Premiums recorded in other current assets on natural gas contracts held | $ 9,500,000 | |
Fair Value Assets, Transfers between Levels | $ 0 | |
Corporate bonds in other assets | 7,000,000 | 6,900,000 |
Treasury notes in other assets | 3,200,000 | 3,500,000 |
Long-term Debt | 3,700,000,000 | |
Fair Value, Inputs, Level 1 [Member] | ||
Fair Value, Assets and Liabilities Measured on Recurring Basis [Line Items] | ||
Fair value, natural gas call options | 2,300,000 | |
Fair Value, Inputs, Level 2 [Member] | ||
Fair Value, Assets and Liabilities Measured on Recurring Basis [Line Items] | ||
Long-term Debt, Fair Value | $ 3,700,000,000 | $ 3,900,000,000 |