SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Policy)	12 Months Ended
Dec. 31, 2022
Accounting Policies [Abstract]
Principles of Consolidation	The consolidated financial statements include the accounts of Unit Corporation and its subsidiaries. We consolidated the financial position, operating results, and cash flows of Superior prior to March 1, 2022, on which date the Master Services and Operating Agreement (MSA) was amended and restated, with the result that we no longer consolidate Superior's financial position, operating results, and cash flows during periods subsequent to March 1, 2022. Accordingly, the 2022 consolidated financial statements and notes reflect Superior activity on a consolidated basis for the two months prior to March 1, 2022. See Note 19 – Superior Investment for more information on the Superior investment and consolidation conclusions. All intercompany transactions and accounts between consolidated entities have been eliminated, including activity between Unit and Superior during the two months prior to March 1, 2022. Affiliate transactions and accounts between Unit and Superior subsequent to March 1, 2022 are not eliminated. During 2021, management identified an error in the initial allocation of equity between Unit Corporation and non-controlling interests as of the September 3, 2020 fresh start accounting date. The impact of the error was not material to any of our prior period financial statements and the error was corrected with one-time adjustment during the year ended December 31, 2021. As a result, during the year ended December 31, 2021, retained earnings (deficit) was reduced by $1.4 million with a corresponding decrease to non-controlling interest in consolidated subsidiaries. Certain amounts presented for prior periods have been reclassified to conform to current year presentation. There was no impact from these reclassifications to consolidated net income or shareholders' equity. We evaluated our disclosure of subsequent events through March 17, 2023, the date the consolidated financial statements were issued.
Accounting Estimates	Preparing financial statements in conformity with U.S. GAAP requires management to make estimates and assumptions that affect the reported amounts and disclosures in the consolidated financial statements. Actual results could differ from those estimates. Significant estimates and assumptions include: •oil and gas reserves quantities and values; •full cost ceiling test and impairment assessments for property and equipment; •asset retirement obligations; •fair value of commodity derivative assets and liabilities; •fair value of the warrant liability; •fair value of stock-based compensation grants or modifications; •workers' compensation liabilities; •fair value of our retained investment in Superior; •contingency, litigation, and environmental liabilities; and •realizability of deferred tax assets.
Cash Equivalents and Bank Overdrafts	We include as cash and cash equivalents all cash on hand and on deposit, as well as highly liquid investments with maturities of three months or less which are readily convertible into known amounts of cash. The financing section of our consolidated statements of cash flows reflects bank overdraft activity. Bank overdrafts are checks issued before the end of the period, but not presented to our bank for payment before the end of the period. There were no bank overdrafts as of December 31, 2022 or December 31, 2021.
Accounts Receivable	Accounts receivable are carried on a gross basis, with no discounting, less an allowance for expected credit losses. We estimate the allowance for credit losses based on existing economic conditions, the financial condition of our customers, and the amount and age of past due accounts. Receivables are considered past due if full payment is not received by the contractual due date. Past due accounts are generally written off against the allowance for credit losses only after all collection attempts have been unsuccessful.
Property and Equipment	Drilling equipment, gas gathering and processing equipment, transportation equipment, and other property and equipment are carried at cost less accumulated depreciation. Renewals and enhancements are capitalized while repairs and maintenance are expensed. We depreciate all drilling assets utilizing the straight-line method over the estimated useful lives of the assets, typically ranging from four to ten years. Depreciation of other property and equipment is computed using the straight-line method over the estimated useful lives of the assets, typically ranging from three to 15 years. Impairment and disposal. We review the carrying amounts of long-lived assets for potential impairment when events or changes in circumstances suggest the carrying amounts may not be recoverable. Changes that could prompt an assessment include equipment obsolescence, declines in the market demand for a an asset, declines in commodity prices, periods of relatively low drilling rig utilization, declining revenue or cash margin per day, or overall unfavorable changes in general market conditions. Assets are determined to be impaired if a forecast of undiscounted estimated future net operating cash flows directly related to the asset, including disposal value, if any, is less than the carrying amount of the asset. If any asset is determined to be impaired, the loss is measured as the amount by which the carrying asset exceeds its fair value. The estimate of fair value is based on the best information available, including prices for similar assets. Changes in these estimates could cause us to reduce the carrying value of property and equipment. Asset impairment evaluations are, by nature, highly subjective. They involve expectations about future cash flows generated by our assets and reflect our assumptions and judgments regarding future industry conditions and their effect on future utilization levels, dayrates, and costs. Using different estimates and assumptions could result in materially different carrying values of our assets. When property and equipment components are disposed of, the cost and the related accumulated depreciation are removed from the accounts and any resulting gain or loss is generally reflected in income from operations. For dispositions of drill pipe and drill collars, an average cost for the appropriate feet of drill pipe and drill collars is removed from the asset account and charged to accumulated depreciation and proceeds, if any, are credited to accumulated depreciation unless proceeds would exceed remaining cost, in which case excess proceeds are recorded as a gain on disposition of assets.
Capitalized Interest	We did not capitalize any interest costs during the years ended December 31, 2022 and 2021.
Oil and Natural Gas Operations	Leases. We enter into various agreements to lease equipment and buildings, and we review each agreement to determine if they contain operating or finance leases with a term greater than 12 months. We recognize a lease liability on identified leases for the obligation to make lease payments and a right-of-use asset for the right to use the underlying asset for the lease term based on the present value of lease payments over the lease term which includes all noncancelable periods as well as periods covered by options to extend the lease that we are reasonably certain to exercise. Leases with an initial term of 12 months or less are not recorded as a lease right-of-use asset and liability. Most leases are valued using an incremental borrowing rate, which is determined based on information available at the commencement date of a lease, as an implicit borrowing rate cannot be determined under most of our leases. Leases may include renewal, purchase or termination options that can extend or shorten the term of the lease. These options are evaluated at inception and throughout the contract term to determine if a modification of the lease term is required. Leases with an initial term of 12 months or less are not recorded as a lease right-of-use asset and liability. Expenses related to leases determined to be operating leases will be recognized on a straight-line basis over the lease term including any reasonably certain renewal periods, while those determined to be finance leases will be recognized following a front-loaded expense profile in which interest and amortization are presented separately in the consolidated statements of operations. The determination of whether a lease is accounted for as a finance lease or an operating lease requires management's estimates of the fair value of the underlying asset and its estimated economic useful life, among other considerations.
ARO	The estimated liabilities related to these future costs are recorded at the time the wells are drilled or acquired. We use historical experience to determine the estimated plugging costs considering the well's type, depth, physical location, and ultimate productive life. A risk-adjusted discount rate and an inflation factor are applied to estimate the present value of these obligations. We depreciate the capitalized asset retirement cost and accrete the obligation over time. Revisions to the obligations and assets are recognized at the appropriate risk-adjusted discount rate with a corresponding adjustment made to the full cost pool. Our mid-stream investment has property and equipment at locations leased or under right of way agreements which may require asset removal or site restoration, however, prior to the deconsolidation of Superior, we were not able to reasonably measure the fair value of the obligations as the potential settlement dates were indeterminable.
Insurance	We are self-insured for certain losses relating to workers’ compensation, control of well, and employee medical benefits. Insured policies for other coverage contain deductibles or retentions per occurrence that range from zero to $1.0 million. We have purchased stop-loss coverage to limit, to the extent feasible, per occurrence and aggregate exposure to certain types of claims. There is no assurance that the insurance coverages we have will adequately protect us against liability from all potential consequences. If insurance coverage becomes more expensive, we may choose to self-insure, decrease our limits, raise our deductibles, or any combination of these rather than pay higher premiums.
Derivative Activities	All commodity derivatives are recognized on the consolidated balance sheets as either an asset or liability measured at fair value and all our commodity derivative counterparties are subject to master netting agreements. We net the value of the derivative transactions with the same counterparty if a legal right to set-off exists. Changes in the fair value of our commodity derivatives and gains or losses on commodity derivative settlement are reported in loss on derivatives in our consolidated statements of operations. Cash settlements received or paid for matured, early-terminated, and/or modified derivatives are reported in cash payments on derivatives settled in our consolidated statements of cash flows.
Income Taxes	Income taxes are recognized based on earnings reported for tax return purposes in addition to a provision for deferred income taxes. Deferred income taxes are recognized at the end of each reporting period for the future tax consequences of cumulative temporary differences between the tax basis of assets and liabilities and their reported amounts in the Company’s consolidated financial statements based on existing tax laws and enacted statutory tax rates applicable to the periods in which the temporary differences are expected to affect taxable income. U.S. GAAP requires the recognition of a deferred tax asset for net operating loss carryforwards and tax credit carryforwards. We periodically assesses the realizability of the deferred tax assets by considering all available evidence (both positive and negative) to determine whether it is more likely than not that all or a portion of the deferred tax assets will not be realized and a valuation allowance is required.
Natural Gas Balancing	When there are insufficient remaining reserves to offset a gas imbalance, we recognize an asset or a liability for the under-produced or over-produced position. We have recorded a receivable of $3.5 million and a liability of $4.3 million as of December 31, 2022 on certain properties where we estimate that insufficient reserves are available for us to recover our under-production from future production volumes or insufficient reserves available to allow the under-produced owners to recover their under-production from future production volumes, respectively. Our policy is to expense the pro-rata share of lease operating costs from all wells as incurred. Such expenses relating to the balancing position on wells in which we have imbalances are not material.
Employee And Director Stock Based Compensation	We recognize the cost of stock-based compensation over the requisite service periods, which is generally the vesting period, based on the grant date fair value of those awards and account for forfeitures as they occur. Warrant Liability. Prior to the determination of the initial exercise price, we recognized the fair value of the warrants as a derivative liability on our consolidated balance sheets with changes in the liability reported as loss on change in fair value of warrants in our consolidated statements of operations. On April 7, 2022, the Company delivered notice of the initial $63.74 exercise price resulting in the warrants meeting the definition of an equity instrument. Accordingly, we recognized the change in the fair value of the warrant liability in our unaudited condensed consolidated statements of operations and reclassified the $49.1 million warrant liability to capital in excess of par value on the unaudited condensed consolidated balance sheets as of April 7, 2022. The warrants will continue to be reported as capital in excess of par value and are no longer subject to future fair value adjustments.
New Accounting Standards
Revenue	Our revenue streams are reported under three segments: oil and natural gas, contract drilling, and mid-stream which is consistent with how we report our segment revenue in Note 22 – Industry Segment Information. Revenue from the oil and natural gas segment is from sales of our oil and natural gas production. Revenue from the contract drilling segment comes from contracting with upstream companies to drill an agreed-on number of wells or provide drilling rigs and services over an agreed-on period. Revenues from the mid-stream segment are generated from the fees earned for gas gathering and processing services provided to a customer or by selling of hydrocarbons to other mid-stream companies. Oil and Natural Gas Revenue Typical types of revenue contracts entered into by our oil and gas segment are Oil Sales Contracts, North American Energy Standards Board (NAESB) Contracts, Gas Gathering and Processing Agreements, and revenues earned as the non-operated party with the operator serving as an agent on our behalf under joint operating agreements. Consideration received is variable and settled monthly while contract terms can range from a single month or evergreen to terms of a decade or more. Revenues from oil and natural gas sales are recognized when the customer obtains control of the sold product which typically occurs at the point of delivery to the customer. Certain costs, as either a deduction from revenue or as an expense, are determined based on when control of the commodity is transferred to our customer, which would affect our total revenue recognized, but will not affect gross profit. For example, gathering, processing and transportation costs are included as part of the contract price with the customer on transfer of control of the commodity are included in the transaction price, while costs incurred while we are in control of the commodity represent operating costs. Contract Drilling Revenue Contract drilling revenues and expenses are primarily recognized as services are performed and collection is reasonably assured. Payments for mobilization and demobilization activities do not relate to a distinct good or service within the contract, but are recognized as revenue when received as deferral for ratable recognition over the contract term is not material to the consolidated financial statements. Costs incurred to relocate rigs and other drilling equipment to areas in which a contract has not been secured are expensed as incurred and any reimbursements received for out-of-pocket expenses are recorded as both revenues and direct costs. Most of our drilling contracts have a term of one year or less and the remaining performance obligations under the contracts without a fixed term are not material. Mid-Stream Revenue The typical revenue contracts used by this segment are gas gathering and processing agreements as well as product sales. Superior recognizes sales revenue at the point in time when control transfers to the purchaser, typically at a specified delivery point, based on the contractually agreed upon fixed or index-based price received. Contracts for gas gathering and processing services may include terms for demand fees or shortfall fees. Demand fees or shortfall fees exist in arrangements where a customer agrees to pay a fixed fee for a contractually agreed upon pipeline capacity or shortfall fees for any minimum volumes not utilized, which create performance obligations for each individual period of reservation. Revenue for these fees is recognized once the services have been completed, the customer no longer has access to the contracted capacity, or the likelihood of the customer exercising all or a portion of their remaining rights becomes remote.

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Policy)

12 Months Ended

Dec. 31, 2022

The consolidated financial statements include the accounts of Unit Corporation and its subsidiaries. We consolidated the financial position, operating results, and cash flows of Superior prior to March 1, 2022, on which date the Master Services and Operating Agreement (MSA) was amended and restated, with the result that we no longer consolidate Superior's financial position, operating results, and cash flows during periods subsequent to March 1, 2022. Accordingly, the 2022 consolidated financial statements and notes reflect Superior activity on a consolidated basis for the two months prior to March 1, 2022. See Note 19 – Superior Investment for more information on the Superior investment and consolidation conclusions. All intercompany transactions and accounts between consolidated entities have been eliminated, including activity between Unit and Superior during the two months prior to March 1, 2022. Affiliate transactions and accounts between Unit and Superior subsequent to March 1, 2022 are not eliminated.

During 2021, management identified an error in the initial allocation of equity between Unit Corporation and non-controlling interests as of the September 3, 2020 fresh start accounting date. The impact of the error was not material to any of our prior period financial statements and the error was corrected with one-time adjustment during the year ended December 31, 2021. As a result, during the year ended December 31, 2021, retained earnings (deficit) was reduced by $1.4 million with a corresponding decrease to non-controlling interest in consolidated subsidiaries.

Certain amounts presented for prior periods have been reclassified to conform to current year presentation. There was no impact from these reclassifications to consolidated net income or shareholders' equity.

We evaluated our disclosure of subsequent events through March 17, 2023, the date the consolidated financial statements were issued.

Accounting Estimates

Preparing financial statements in conformity with U.S. GAAP requires management to make estimates and assumptions that affect the reported amounts and disclosures in the consolidated financial statements. Actual results could differ from those estimates. Significant estimates and assumptions include:

•oil and gas reserves quantities and values;

•full cost ceiling test and impairment assessments for property and equipment;

•asset retirement obligations;

•fair value of commodity derivative assets and liabilities;

•fair value of the warrant liability;

•fair value of stock-based compensation grants or modifications;

•workers' compensation liabilities;

•fair value of our retained investment in Superior;

•contingency, litigation, and environmental liabilities; and

•realizability of deferred tax assets.

Cash Equivalents and Bank Overdrafts

We include as cash and cash equivalents all cash on hand and on deposit, as well as highly liquid investments with maturities of three months or less which are readily convertible into known amounts of cash. The financing section of our consolidated statements of cash flows reflects bank overdraft activity. Bank overdrafts are checks issued before the end of the period, but not presented to our bank for payment before the end of the period. There were no bank overdrafts as of December 31, 2022 or December 31, 2021.

Accounts Receivable

Accounts receivable are carried on a gross basis, with no discounting, less an allowance for expected credit losses. We estimate the allowance for credit losses based on existing economic conditions, the financial condition of our customers, and the amount and age of past due accounts. Receivables are considered past due if full payment is not received by the contractual due date. Past due accounts are generally written off against the allowance for credit losses only after all collection attempts have been unsuccessful.

Property and Equipment

Drilling equipment, gas gathering and processing equipment, transportation equipment, and other property and equipment are carried at cost less accumulated depreciation. Renewals and enhancements are capitalized while repairs and maintenance are expensed. We depreciate all drilling assets utilizing the straight-line method over the estimated useful lives of the assets, typically ranging from four to ten years. Depreciation of other property and equipment is computed using the straight-line method over the estimated useful lives of the assets, typically ranging from three to 15 years.

Impairment and disposal. We review the carrying amounts of long-lived assets for potential impairment when events or changes in circumstances suggest the carrying amounts may not be recoverable. Changes that could prompt an assessment include equipment obsolescence, declines in the market demand for a an asset, declines in commodity prices, periods of relatively low drilling rig utilization, declining revenue or cash margin per day, or overall unfavorable changes in general market conditions. Assets are determined to be impaired if a forecast of undiscounted estimated future net operating cash flows directly related to the asset, including disposal value, if any, is less than the carrying amount of the asset. If any asset is determined to be impaired, the loss is measured as the amount by which the carrying asset exceeds its fair value. The estimate of fair value is based on the best information available, including prices for similar assets. Changes in these estimates could cause us to reduce the carrying value of property and equipment. Asset impairment evaluations are, by nature, highly subjective. They involve expectations about future cash flows generated by our assets and reflect our assumptions and judgments regarding future industry conditions and their effect on future utilization levels, dayrates, and costs. Using different estimates and assumptions could result in materially different carrying values of our assets.

When property and equipment components are disposed of, the cost and the related accumulated depreciation are removed from the accounts and any resulting gain or loss is generally reflected in income from operations. For dispositions of drill pipe and drill collars, an average cost for the appropriate feet of drill pipe and drill collars is removed from the asset account and charged to accumulated depreciation and proceeds, if any, are credited to accumulated depreciation unless proceeds would exceed remaining cost, in which case excess proceeds are recorded as a gain on disposition of assets.

Capitalized Interest

We did not capitalize any interest costs during the years ended December 31, 2022 and 2021.

Oil and Natural Gas Operations

Leases. We enter into various agreements to lease equipment and buildings, and we review each agreement to determine if they contain operating or finance leases with a term greater than 12 months. We recognize a lease liability on identified leases for the obligation to make lease payments and a right-of-use asset for the right to use the underlying asset for the lease term based on the present value of lease payments over the lease term which includes all noncancelable periods as well as periods covered by options to extend the lease that we are reasonably certain to exercise. Leases with an initial term of 12 months or less are not recorded as a lease right-of-use asset and liability. Most leases are valued using an incremental borrowing rate, which is determined based on information available at the commencement date of a lease, as an implicit borrowing rate cannot be determined under most of our leases. Leases may include renewal, purchase or termination options that can extend or shorten the term of the lease. These options are evaluated at inception and throughout the contract term to determine if a modification of the lease term is required. Leases with an initial term of 12 months or less are not recorded as a lease right-of-use asset and liability.

Expenses related to leases determined to be operating leases will be recognized on a straight-line basis over the lease term including any reasonably certain renewal periods, while those determined to be finance leases will be recognized following a front-loaded expense profile in which interest and amortization are presented separately in the consolidated statements of operations. The determination of whether a lease is accounted for as a finance lease or an operating lease requires management's estimates of the fair value of the underlying asset and its estimated economic useful life, among other considerations.

ARO

The estimated liabilities related to these future costs are recorded at the time the wells are drilled or acquired. We use historical experience to determine the estimated plugging costs considering the well's type, depth, physical location, and ultimate productive life. A risk-adjusted discount rate and an inflation factor are applied to estimate the present value of these obligations. We depreciate the capitalized asset retirement cost and accrete the obligation over time. Revisions to the obligations and assets are recognized at the appropriate risk-adjusted discount rate with a corresponding adjustment made to the full cost pool. Our mid-stream investment has property and equipment at locations leased or under right of way agreements which may require asset removal or site restoration, however, prior to the deconsolidation of Superior, we were not able to reasonably measure the fair value of the obligations as the potential settlement dates were indeterminable.

Insurance

We are self-insured for certain losses relating to workers’ compensation, control of well, and employee medical benefits. Insured policies for other coverage contain deductibles or retentions per occurrence that range from zero to $1.0 million. We have purchased stop-loss coverage to limit, to the extent feasible, per occurrence and aggregate exposure to certain types of claims. There is no assurance that the insurance coverages we have will adequately protect us against liability from all potential consequences. If insurance coverage becomes more expensive, we may choose to self-insure, decrease our limits, raise our deductibles, or any combination of these rather than pay higher premiums.

Derivative Activities

All commodity derivatives are recognized on the consolidated balance sheets as either an asset or liability measured at fair value and all our commodity derivative counterparties are subject to master netting agreements. We net the value of the derivative transactions with the same counterparty if a legal right to set-off exists. Changes in the fair value of our commodity derivatives and gains or losses on commodity derivative settlement are reported in loss on derivatives in our consolidated statements of operations. Cash settlements received or paid for matured, early-terminated, and/or modified derivatives are reported in cash payments on derivatives settled in our consolidated statements of cash flows.

Income Taxes

Income taxes are recognized based on earnings reported for tax return purposes in addition to a provision for deferred income taxes. Deferred income taxes are recognized at the end of each reporting period for the future tax consequences of cumulative temporary differences between the tax basis of assets and liabilities and their reported amounts in the Company’s consolidated financial statements based on existing tax laws and enacted statutory tax rates applicable to the periods in which the temporary differences are expected to affect taxable income. U.S. GAAP requires the recognition of a deferred tax asset for net operating loss carryforwards and tax credit carryforwards. We periodically assesses the realizability of the deferred tax assets by considering all available evidence (both positive and negative) to determine whether it is more likely than not that all or a portion of the deferred tax assets will not be realized and a valuation allowance is required.

Natural Gas Balancing

When there are insufficient remaining reserves to offset a gas imbalance, we recognize an asset or a liability for the under-produced or over-produced position. We have recorded a receivable of $3.5 million and a liability of $4.3 million as of December 31, 2022 on certain properties where we estimate that insufficient reserves are available for us to recover our under-production from future production volumes or insufficient reserves available to allow the under-produced owners to recover their under-production from future production volumes, respectively. Our policy is to expense the pro-rata share of lease operating costs from all wells as incurred. Such expenses relating to the balancing position on wells in which we have imbalances are not material.

Employee And Director Stock Based Compensation

We recognize the cost of stock-based compensation over the requisite service periods, which is generally the vesting period, based on the grant date fair value of those awards and account for forfeitures as they occur. Warrant Liability. Prior to the determination of the initial exercise price, we recognized the fair value of the warrants as a derivative liability on our consolidated balance sheets with changes in the liability reported as loss on change in fair value of warrants in our consolidated statements of operations. On April 7, 2022, the Company delivered notice of the initial $63.74 exercise price resulting in the warrants meeting the definition of an equity instrument. Accordingly, we recognized the change in the fair value of the warrant liability in our unaudited condensed consolidated statements of operations and reclassified the $49.1 million warrant liability to capital in excess of par value on the unaudited condensed consolidated balance sheets as of April 7, 2022. The warrants will continue to be reported as capital in excess of par value and are no longer subject to future fair value adjustments.

New Accounting Standards

Revenue

Our revenue streams are reported under three segments: oil and natural gas, contract drilling, and mid-stream which is consistent with how we report our segment revenue in Note 22 – Industry Segment Information. Revenue from the oil and natural gas segment is from sales of our oil and natural gas production. Revenue from the contract drilling segment comes from contracting with upstream companies to drill an agreed-on number of wells or provide drilling rigs and services over an agreed-on period. Revenues from the mid-stream segment are generated from the fees earned for gas gathering and processing services provided to a customer or by selling of hydrocarbons to other mid-stream companies.

Oil and Natural Gas Revenue

Typical types of revenue contracts entered into by our oil and gas segment are Oil Sales Contracts, North American Energy Standards Board (NAESB) Contracts, Gas Gathering and Processing Agreements, and revenues earned as the non-operated party with the operator serving as an agent on our behalf under joint operating agreements. Consideration received is variable and settled monthly while contract terms can range from a single month or evergreen to terms of a decade or more. Revenues from oil and natural gas sales are recognized when the customer obtains control of the sold product which typically occurs at the point of delivery to the customer.

Certain costs, as either a deduction from revenue or as an expense, are determined based on when control of the commodity is transferred to our customer, which would affect our total revenue recognized, but will not affect gross profit. For example, gathering, processing and transportation costs are included as part of the contract price with the customer on transfer of control of the commodity are included in the transaction price, while costs incurred while we are in control of the commodity represent operating costs.

Contract Drilling Revenue

Contract drilling revenues and expenses are primarily recognized as services are performed and collection is reasonably assured. Payments for mobilization and demobilization activities do not relate to a distinct good or service within the contract, but are recognized as revenue when received as deferral for ratable recognition over the contract term is not material to the consolidated financial statements. Costs incurred to relocate rigs and other drilling equipment to areas in which a contract has not been secured are expensed as incurred and any reimbursements received for out-of-pocket expenses are recorded as both revenues and direct costs.

Most of our drilling contracts have a term of one year or less and the remaining performance obligations under the contracts without a fixed term are not material.

Mid-Stream Revenue

The typical revenue contracts used by this segment are gas gathering and processing agreements as well as product sales. Superior recognizes sales revenue at the point in time when control transfers to the purchaser, typically at a specified delivery point, based on the contractually agreed upon fixed or index-based price received. Contracts for gas gathering and processing services may include terms for demand fees or shortfall fees. Demand fees or shortfall fees exist in arrangements where a customer agrees to pay a fixed fee for a contractually agreed upon pipeline capacity or shortfall fees for any minimum volumes not utilized, which create performance obligations for each individual period of reservation. Revenue for these fees is recognized once the services have been completed, the customer no longer has access to the contracted capacity, or the likelihood of the customer exercising all or a portion of their remaining rights becomes remote.