Unit (UNTC) 10-Q 6 Nov 18 2018 Q3 Quarterly report Financial data

Document And Entity Information

Document And Entity Information - shares	9 Months Ended
	Sep. 30, 2018	Oct. 19, 2018
Document Information [Line Items]
Document Type	10-Q
Amendment Flag	false
Document Period End Date	Sep. 30, 2018
Document Fiscal Year Focus	2,018
Document Fiscal Period Focus	Q3
Trading Symbol	unt
Entity Registrant Name	UNIT CORP
Entity Central Index Key	798,949
Current Fiscal Year End Date	--12-31
Entity Filer Category	Large Accelerated Filer
Entity Common Stock, Shares Outstanding		54,058,016

Condensed Consolidated Balance

Condensed Consolidated Balance Sheets (Unaudited) - USD ($)	Sep. 30, 2018		Dec. 31, 2017
Current assets:
Cash and cash equivalents	$ 91,557,000		$ 701,000
Accounts receivable, net of allowance for doubtful accounts of $2,450 at both September 30, 2018 and December 31, 2017, respectively	122,123,000		111,512,000
Materials and supplies	505,000		505,000
Current derivative asset (Note 10)	0		721,000
Prepaid expenses and other	9,419,000		6,233,000
Total current assets	223,604,000		119,672,000
Oil and natural gas properties on the full cost method:
Proved properties	5,901,661,000		5,712,813,000
Unproved properties not being amortized	332,886,000		296,764,000
Drilling equipment	1,632,540,000		1,593,611,000
Gas gathering and processing equipment	751,715,000		726,236,000
Saltwater disposal systems	67,074,000		62,618,000
Corporate land and building	59,081,000		59,080,000
Transportation equipment	29,103,000		29,631,000
Other	56,750,000		53,439,000
Property, plant, and equipment, gross	8,830,810,000		8,534,192,000
Less accumulated depreciation, depletion, amortization, and impairment	6,325,160,000		6,151,450,000
Net property and equipment	2,505,650,000		2,382,742,000
Goodwill	62,808,000		62,808,000
Other assets	28,703,000		16,230,000
Total assets	2,820,765,000	[1]	2,581,452,000
Current liabilities:
Accounts payable	143,552,000		112,648,000
Accrued liabilities (Note 5)	67,743,000		48,523,000
Income taxes payable	1,051,000		0
Current derivative liability (Note 10)	13,067,000		7,763,000
Current portion of other long-term liabilities (Note 6)	14,150,000		13,002,000
Total current liabilities	239,563,000		181,936,000
Long-term debt less debt issuance costs (Note 6)	643,921,000		820,276,000
Non-current derivative liability (Note 10)	1,542,000		0
Other long-term liabilities (Note 6)	101,410,000		100,203,000
Deferred income taxes	164,964,000		133,477,000
Commitments and contingencies (Note 12)	0		0
Shareholders' equity:
Preferred stock, $1.00 par value, 5,000,000 shares authorized, none issued	0		0
Common stock, $.20 par value, 175,000,000 shares authorized, 54,063,705 and 52,880,134 shares issued as of September 30, 2018 and December 31, 2017, respectively	10,414,000		10,280,000
Capital in excess of par value	626,746,000		535,815,000
Accumulated other comprehensive income (loss) (Note 14)	(103,000)		63,000
Retained earnings	830,680,000		799,402,000
Total shareholders’ equity attributable to Unit Corporation	1,467,737,000		1,345,560,000
Non-controlling interests in consolidated subsidiaries	201,628,000		0
Total shareholders' equity	1,669,365,000		1,345,560,000
Total liabilities and shareholders' equity	$ 2,820,765,000	[1]	$ 2,581,452,000
[1]	Unit Corporation's consolidated total assets as of September 30, 2018 include total current and long-term assets of its variable interest entity (VIE) (Superior Pipeline Company, L.L.C.) of $41.8 million and $416.7 million, respectively, which can only be used to settle obligations of the VIE. Unit Corporation's consolidated total liabilities as of September 30, 2018 include total current and long-term liabilities of the VIE of $38.6 million and $16.1 million, respectively, for which the creditors of the VIE have no recourse to Unit Corporation. See Note 13 – Variable Interest Entity Arrangements.

Condensed Consolidated Balanc_2

Condensed Consolidated Balance Sheets (Unaudited) (Parenthetical) - USD ($) $ in Thousands	Sep. 30, 2018	Dec. 31, 2017
Statement of Financial Position [Abstract]
Accounts receivable, allowance for doubtful accounts	$ 2,450	$ 2,450
Preferred stock, par value	$ 1	$ 1
Preferred stock, shares authorized	5,000,000	5,000,000
Preferred stock, shares issued	0	0
Common stock, par value	$ 0.20	$ 0.20
Common stock, shares authorized	175,000,000	175,000,000
Common stock, shares issued	54,063,705	52,880,134
VIE Current Assets Pledged	$ 41,786
VIE Non-current Assets Pledged	416,714
VIE Current Liabilities, No Recourse	38,593
VIE Non-current Liabilities, No Recourse	$ 16,126

Condensed Consolidated Income S

Condensed Consolidated Income Statements (Unaudited) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 2017
Revenues:
Oil and natural gas	$ 111,623	$ 85,470	$ 317,040	$ 256,241
Contract drilling	50,612	51,619	143,527	128,059
Gas gathering and processing	57,823	51,399	167,926	150,493
Total revenues	220,058	188,488	628,493	534,793
Operating costs:
Oil and natural gas	32,139	33,911	100,519	95,873
Contract drilling	32,032	34,747	95,593	91,213
Gas gathering and processing	43,134	38,116	124,441	111,862
Total operating costs	107,305	106,774	320,553	298,948
Depreciation, depletion, and amortization	63,537	54,533	178,976	151,545
General and administrative	9,278	9,235	28,752	26,902
Gain on disposition of assets	(253)	(81)	(575)	(1,153)
Total operating expenses	179,867	170,461	527,706	476,242
Income from operations	40,191	18,027	100,787	58,551
Other income (expense):
Interest, net	(7,945)	(9,944)	(25,678)	(28,807)
Gain (loss) on derivatives	(4,385)	(2,614)	(25,608)	21,019
Other, net	6	5	17	14
Total other income (expense)	(12,324)	(12,553)	(51,269)	(7,774)
Income before income taxes	27,867	5,474	49,518	50,777
Income tax expense:
Deferred	6,744	1,769	12,380	22,084
Total income taxes	6,744	1,769	12,380	22,084
Net income	21,123	3,705	37,138	28,693
Net income attributable to non-controlling interest	2,224	0	4,586	0
Net income attributable to Unit Corporation	$ 18,899	$ 3,705	$ 32,552	$ 28,693
Net income attributable to Unit Corporation per common share:
Basic	$ 0.36	$ 0.07	$ 0.63	$ 0.56
Diluted	$ 0.36	$ 0.07	$ 0.62	$ 0.56

Condensed Consolidated Statemen

Condensed Consolidated Statements of Comprehensive Income (Unaudited) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 2017
Statement of Comprehensive Income [Abstract]
Net income	$ 21,123	$ 3,705	$ 37,138	$ 28,693
Other comprehensive income (loss), net of taxes:
Unrealized gain (loss) on securities, net of tax of ($13), $20, ($60) and $32	(38)	33	(179)	53
Comprehensive income	21,085	3,738	36,959	28,746
Less: Comprehensive income attributable to non-controlling interest	2,224	0	4,586	0
Comprehensive income attributable to Unit Corporation	$ 18,861	$ 3,738	$ 32,373	$ 28,746

Condensed Consolidated Statem_2

Condensed Consolidated Statements of Comprehensive Income (Unaudited) (Parenthetical) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 2017
Statement of Comprehensive Income [Abstract]
Unrealized income (loss) on securities, tax	$ (13)	$ 20	$ (60)	$ 32

Condensed Consolidated Statem_3

Condensed Consolidated Statements of Changes in Shareholders' Equity (Unaudited) - USD ($) $ in Thousands	Total	Common Stock [Member]	Capital In Excess of Par Value [Member]	Accumulated other comprehensive income [Member]	Retained earnings [Member]	Non-controlling interests in consolidated subsidiaries [Member]
Stockholders' equity, beginning balance at Dec. 31, 2016	$ 1,194,070	$ 10,016	$ 502,500	$ 0	$ 681,554	$ 0
Net Income	28,693	0	0	0	28,693	0
Other comprehensive income (loss)	53	0	0	53	0	0
Total comprehensive income	28,746
Activity in employee compensation plans	29,089	261	28,828	0	0	0
Stockholders' equity, ending balance at Sep. 30, 2017	1,251,905	10,277	531,328	53	710,247	0
Cumulative effect adjustment for adoption of ASUs (Notes 1 and 2)	(1,261)	0	0	13	(1,274)	0
Stockholders' equity, beginning balance at Dec. 31, 2017	1,345,560	10,280	535,815	63	799,402	0
Net Income	37,138	0	0	0	32,552	4,586
Other comprehensive income (loss)	(179)	0	0	(179)	0	0
Total comprehensive income	36,959
Contributions	300,000	0	102,958	0	0	197,042
Transaction costs associated with sale of non-controlling interest	(2,303)	0	(2,303)	0	0	0
Tax effect of sale on non-controlling interest	(24,300)	0	(24,300)	0	0	0
Activity in employee compensation plans	14,710	134	14,576	0	0	0
Stockholders' equity, ending balance at Sep. 30, 2018	$ 1,669,365	$ 10,414	$ 626,746	$ (103)	$ 830,680	$ 201,628

Condensed Consolidated Statem_4

Condensed Consolidated Statements of Changes in Shareholders' Equity (Unaudited) (Parenthetical) - shares shares in Thousands	9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017
Statement of Stockholders' Equity [Abstract]
Activity in employee compensation plans (shares)	1,183,571	1,385,342

Condensed Consolidated Statem_5

Condensed Consolidated Statements of Cash Flows (Unaudited) - USD ($) $ in Thousands	9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017
OPERATING ACTIVITIES:
Net income	$ 37,138	$ 28,693
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, depletion, and amortization	178,976	151,545
Amortization of debt issuance costs and debt discount (Note 6)	1,645	1,616
(Gain) loss on derivatives (Note 10)	25,608	(21,019)
Cash payments on derivatives settled, net (Note 10)	(18,040)	(729)
Deferred tax expense	12,380	22,084
Gain on disposition of assets	(575)	(1,153)
Stock compensation plans	17,397	12,478
Contract assets and liabilities, net (Note 2)	(3,671)	0
Other, net	2,835	1,397
Changes in operating assets and liabilities increasing (decreasing) cash:
Accounts receivable	(15,558)	(36,381)
Accounts payable	(14,867)	4,873
Material and supplies	0	17
Income taxes	0	(15)
Accrued liabilities	16,242	20,280
Other, net	(2,975)	1,106
Net cash provided by operating activities	236,535	184,792
INVESTING ACTIVITIES:
Capital expenditures	(304,054)	(167,392)
Producing properties and other acquisitions	(769)	(55,429)
Proceeds from disposition of assets	25,316	20,137
Other	0	(1,500)
Net cash used in investing activities	(279,507)	(204,184)
FINANCING ACTIVITIES:
Borrowings under credit agreement	71,200	251,401
Payments under credit agreement	(249,200)	(250,100)
Payments on capitalized leases	(2,869)	(2,967)
Proceeds from common stock issued, net of issue costs (Note 14)	0	18,623
Proceeds from investments of non-controlling interests	300,000	0
Transaction costs associated with non-controlling interests	(2,303)	0
Book overdrafts	17,000	2,364
Net cash provided by financing activities	133,828	19,321
Net increase (decrease) in cash and cash equivalents	90,856	(71)
Cash and cash equivalents, beginning of period	701	893
Cash and cash equivalents, end of period	91,557	822
Cash paid during the year for:
Interest paid (net of capitalized)	14,418	14,601
Income taxes	3,600	0
Changes in accounts payable and accrued liabilities related to purchases of property, plant, and equipment	(28,770)	(20,122)
Non-cash (addition) reduction to oil and natural gas properties related to asset retirement obligations	$ 8,546	$ (3,203)

Basis of Preparation and Presen

Basis of Preparation and Presentation	9 Months Ended
	Sep. 30, 2018
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Basis of Preparation and Presentation	BASIS OF PREPARATION AND PRESENTATION The unaudited condensed consolidated financial statements in this report include the accounts of Unit Corporation and all its subsidiaries and affiliates and have been prepared under the rules and regulations of the SEC. The terms “company,” “Unit,” “we,” “our,” “us,” or like terms refer to Unit Corporation, a Delaware corporation, and one or more of its subsidiaries and affiliates, except as otherwise indicated or as the context otherwise requires. We consolidate the activities of Superior Pipeline Company, L.L.C. (Superior), a 50/50 joint venture between Unit Corporation and SP Investor Holdings, LLC, which qualifies as a VIE under generally accepted accounting principles in the United States (GAAP). We have concluded that we are the primary beneficiary of the VIE, as defined in the accounting standards, since we have the power, through our 50% ownership, to direct those activities that most significantly affect the economic performance of Superior as further described in Note 13 – Variable Interest Entity Arrangements. The condensed consolidated financial statements are unaudited and do not include all the notes in our annual financial statements. This report should be read with the audited consolidated financial statements and notes in our Form 10-K, filed February 27, 2018, for the year ended December 31, 2017 as amended by our Form 10-K/A filed on August 6, 2018. In the opinion of our management, the unaudited condensed consolidated financial statements contain all normal recurring adjustments (including the elimination of all intercompany transactions) necessary to fairly state: • Balance Sheets at September 30, 2018 and December 31, 2017 ; • Income Statements for the three and nine months ended September 30, 2018 and 2017 ; • Statements of Comprehensive Income for the three and nine months ended September 30, 2018 and 2017 ; • Statements of Changes in Shareholders' Equity for the nine months ended September 30, 2018 and 2017 ; and • Statements of Cash Flows for the nine months ended September 30, 2018 and 2017 . Our financial statements are prepared in conformity with GAAP, which requires us to make certain estimates and assumptions that may affect the amounts reported in our unaudited condensed consolidated financial statements and notes. Actual results may differ from those estimates. Results for the nine months ended September 30, 2018 and 2017 are not necessarily indicative of the results we may realize for the full year of 2018 , or that we realized for the full year of 2017 . Accounting Changes - Recent Accounting Pronouncements - Adopted As of January 1, 2018, we adopted ASU 2018-02 Reclassification of Certain Tax Effects from Accumulated Other Comprehensive Income. This standard is explained further in Note 8 - New Accounting Pronouncements. We adopted this amendment early and it had no material effect to our financial statements. We previously used 37.75% to calculate the tax effect on AOCI and we now use 24.5% . This change is reflected in our Unaudited Condensed Consolidated Statements of Comprehensive Income and in Note 14 - Equity. Also, as of January 1, 2018, we adopted ASU 2014-09 Revenue from Contracts with Customers - Topic 606 (ASC 606) and all later amendments that modified ASC 606. This new revenue standard is explained further in Note 8 – New Accounting Pronouncements. We elected to apply this standard on the modified retrospective approach method to contracts not completed as of January 1, 2018, where the cumulative effect on adoption, which only affected our mid-stream segment, is recognized as an adjustment to opening retained earnings at January 1, 2018. This adjustment related to the timing of revenue recognition for certain demand fees. Our oil and natural gas and contract drilling segments had no retained earnings adjustment. Comparative prior periods have not been adjusted and continue to be reported under ASC 605. The additional disclosures required by the ASU are included in Note 2 – Revenue from Contracts with Customers.

Revenue from Contracts with Cus

Revenue from Contracts with Customers	9 Months Ended
	Sep. 30, 2018
Revenue from Contract with Customer [Abstract]
Revenue from Contract with Customer	REVENUE FROM CONTRACTS WITH CUSTOMERS Our revenue streams are reported under three segments: oil and natural gas, contract drilling, and mid-stream. This is our disaggregation of revenue and how our segment revenue is reported (as reflected in Note 15 – Industry Segment Information). Revenue from the oil and natural gas segment is derived from sales of our oil and natural gas production. Revenue from the contract drilling segment is derived by contracting with upstream companies to drill an agreed-on number of wells or provide drilling rigs and services over an agreed-on time period. Revenue from the mid-stream segment is derived from gathering, transporting, and processing natural gas production and selling those commodities. We sell the hydrocarbons (from the oil and natural gas and mid-stream segments) to mid-stream and downstream oil and gas companies. We satisfy the performance obligation under each segment's contracts as follows: for the contract drilling and mid-stream contracts, we satisfy the performance obligation over the agreed-on time within the contracts, and for oil and natural gas contracts, we satisfy the performance obligation with each delivery of volumes. For oil and natural gas contracts, as it is more feasible, we account for these deliveries monthly. Per the contracts for all segments, customers pay for the services/goods received monthly within an agreed on number of days following the end of the month. Besides the mid-stream demand fees discussed further below, there were no other contract assets or liabilities falling within the scope of this accounting pronouncement. Oil and Natural Gas Contracts, Revenues, Implementation Impact to Retained Earnings, and Performance Obligations Typical types of revenue contracts signed by our segments are Oil Sales Contracts, Gas Purchase Agreements, 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 our Joint Operating Agreements. Contract term can range from a single month to a term spanning a decade or more; some may also include evergreen provisions. Revenues from sales we make are recognized when our customer obtains control of the sold product. For sales to other mid-stream and downstream oil and gas companies, this would occur at a point in time, typically on delivery to the customer. Sales generated from our non-operated interest are recorded based on the information obtained from the operator. Our adoption of this standard required no adjustment to opening retained earnings. Certain costs—as either a deduction from revenue or as an expense—is 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 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. The impact of the adoption of ASC 606 did not impact income from operations or net income for the three or nine months ended September 30, 2018 . These tables summarize the impact of the adoption of ASC 606 on revenue and operating costs for the three and nine months ended September 30, 2018 , respectively: Three Months Ended September 30, 2018 As Reported Adjustments due to ASC 606 Amounts without the Adoption of ASC 606 (In thousands) Oil and natural gas revenues $ 111,623 $ (5,200 ) $ 116,823 Oil and natural gas operating costs 32,139 (5,200 ) 37,339 Gross profit $ 79,484 $ — $ 79,484 Nine Months Ended September 30, 2018 As Reported Adjustments due to ASC 606 Amounts without the Adoption of ASC 606 (In thousands) Oil and natural gas revenues $ 317,040 $ (12,102 ) $ 329,142 Oil and natural gas operating costs 100,519 (12,102 ) 112,621 Gross profit $ 216,521 $ — $ 216,521 Our performance obligation for all commodity contracts is the delivery of oil and gas volumes to the customer. Typically, the contract is for a specified period (for example, a month or a year); however, each delivery under that contract can be considered separately identifiable since each delivery provides benefits to the customer on its own. For feasibility, as accounting for a monthly performance obligation is not materially different than identifying a more granular performance obligation, we conclude this performance obligation is satisfied monthly. We typically receive a payment within a set number of days following the end of the month which includes payment for all deliveries in that month. Depending on contract circumstances, judgment could be required to determine when the transfer of control occurs. Generally, depending of the facts and circumstances, we consider the transfer of control of the asset in a commodity sale to occur at the point the commodity transfers to our purchaser. Most of the consideration received by us for oil and gas sales is variable. Most of our contracts state the consideration is calculated by multiplying a variable quantity by an agreed-on index price less deductions related to gathering, transportation, fractionation, and related fuel charges. There are also instances where the consideration is quantity multiplied by a weighted average sales price. These different pricing tools can change the perception of when control transfers; however, when analyzed with other control factors, typically the accounting conclusion is the same for both pricing methods. In these instances, the variable consideration is partially constrained. In addition, all variable consideration is settled at the end of the month; therefore, whether the variability is constrained does not affect accounting for revenue under ASC 606 as the variability is known prior to each reporting period. An estimation and allocation of transaction price and future obligations are not required. Contract Drilling Contracts, Revenues , Implementation impact to retained earnings, and Performance Obligations The contracts our drilling segment uses are primarily industry standard IADC contracts model year 2003 and 2013. Contract terms range from six months to three or more years or can be based on terms to drill a specific number of wells. The allocation rules in ASC 606 (called the "series guidance") provide that a contract may contain a single performance obligation composed of a series of distinct goods or services if 1) each distinct good or service is substantially the same and would meet the criteria to be a performance obligation satisfied over time and 2) each distinct good or service is measured using the same method as it relates to the satisfaction of the overall performance obligation. We have determined that the delivery of drilling services is within the scope of the series guidance as both criteria noted above are met. Specifically, 1) each distinct increment of service (i.e. hour available to drill) that the drilling contractor promises to transfer represents a performance obligation that would meet the criteria for recognizing revenue over time, and 2) the drilling contractor would use the same method for measuring progress toward satisfaction of the performance obligation for each distinct increment of service in the series. At inception, the total transaction price will be estimated to include any applicable fixed consideration, unconstrained variable consideration (estimated day rate mobilization and demobilization revenue, estimated operating day rate revenue to be earned over the contract term, expected bonuses (if material and can be reasonably estimated without significant reversal), and penalties (if material and can be reasonably estimated without significant reversal)). Allocation rules under this new standard allow us to recognize revenues associated with our drilling contacts in materially the same manner as under the previous revenue accounting standard. A contract liability will be recorded for consideration received before the corresponding transfer of services. Those liabilities will generally only arise in relation to upfront mobilization fees paid in advance and are allocated/recognized over the entire performance obligation. Such balances will be amortized over the recognition period based on the same method of measure used for revenue. On adoption of the standard, no adjustment to opening retained earnings was required. Our performance obligation for all drilling contracts is to drill the agreed-on number of wells or drill over an agreed-on period as stated in the contract. Any mobilization and demobilization activities are not considered distinct within the context of the contract and therefore, any associated revenue is allocated to the overall performance obligation of drilling services and recognized ratably over the initial term of the related drilling contract. It typically takes from 10 to 90 days to complete drilling a well; therefore, depending on the number of wells under a contract, the contract term could be up to three years . Most of the drilling contracts are for less than one year. As the customer simultaneously receives and consumes the benefits provided by the company’s performance, and the company’s performance enhances an asset that the customer controls, the performance obligation to drill the well occurs over time. We typically receive payment within a set number of days following the end of the month and that payment includes payment for all services performed during that month (calculated on an hourly basis). The company satisfies its overall performance obligation when the well included in the contract is drilled to an agreed-on depth or by a set date. All consideration received for contract drilling is variable, excluding termination fees, which we have concluded will not apply to our contracts as of the reporting date. The consideration is calculated by multiplying a variable quantity (number of days/hours) by an agreed-on daily price (for the daily rate, mobilization and demobilization revenue). Other revenue items under the contract may include bonus/penalty revenue, reimbursable revenue, drilling fluid rates, and early termination fees. All variable consideration is not constrained but is settled at the end of the month; therefore, whether the variability is constrained or not does not affect accounting for revenue under ASC 606 as the variability is known before each reporting period excluding certain bonuses/penalties which might be based on activity that occurs over the entire term of the contract. We have evaluated the mobilization and de-mobilization charges on outstanding contracts, however, the impact to the financial statements was immaterial. As of September 30, 2018 , we had 34 contract drilling contracts ( 21 of which are long-term) for a duration of two months to almost three years . Under the guidance in relation to disclosures regarding the remaining performance obligations, there is a practical expedient for contracts with an original expected duration of one year or less (ASC 606-10-50-14) and for contracts where the entity can recognize revenue as invoiced (ASC 606-10-55-18). The majority of our drilling contracts have an original term of less than one year; however, the remaining performance obligations under the contracts that have a longer duration are not material. Mid-stream Contracts Revenues, and Implementation impact to retained earnings, and Performance Obligations Revenues are generated from the fees earned for gas gathering and processing services provided to a customer. The typical revenue contracts used by this segment are gas gathering and processing agreements. Contract terms range from a single month to terms spanning a decade or more, some include evergreen provisions. Fees for mid-stream services (gathering, transportation, processing) are performance obligations and meet the criteria of over time recognition which could be considered a series of distinct performance obligations that represents one overall performance obligation of gas gathering and processing services. On adoption of the standard, an adjustment to opening retained earnings was made for $1.7 million ( $1.3 million , net of tax). This adjustment—related to the timing of revenue recognized on certain demand fees—impacted our Unaudited Condensed Consolidated Balance Sheet (for the periods indicated) as follows: Balance at December 31, 2017 Adjustments due to ASC 606 Balance at January 1, 2018 (In thousands) Assets: Other assets $ 16,230 $ 10,798 $ 27,028 Liabilities and shareholders' equity: Current portion of other long-term liabilities 13,002 2,748 15,750 Other long-term liabilities 100,203 9,737 109,940 Deferred income taxes 133,477 (413 ) 133,064 Retained earnings 799,402 (1,274 ) 798,128 At September 30, 2018 : As Reported Adjustments due to ASC 606 Amounts without the Adoption of ASC 606 (In thousands) Assets: Prepaid expenses and other $ 9,419 $ 206 $ 9,213 Other assets 28,703 12,383 16,320 Liabilities and shareholders' equity: Current portion of other long-term liabilities 14,150 2,874 11,276 Other long-term liabilities 101,410 7,731 93,679 Deferred income taxes 164,964 486 164,478 Retained earnings 830,680 1,498 829,182 For the three months ended September 30, 2018 : As Reported Adjustments due to ASC 606 Amounts without the Adoption of ASC 606 (In thousands) Gas gathering and processing revenues $ 57,823 $ 1,300 $ 56,523 Deferred income tax expense 6,744 318 6,426 Net income 21,123 982 20,141 This adjustment related to the timing of revenue recognized on certain demand fees and had the following impact to the Unaudited Condensed Consolidated Income Statement for the nine months ended September 30, 2018 : As Reported Adjustments due to ASC 606 Amounts without the Adoption of ASC 606 (In thousands) Gas gathering and processing revenues $ 167,926 $ 3,671 $ 164,255 Deferred income tax expense 12,380 899 11,481 Net income 37,138 2,772 34,366 The only fixed consideration related to mid-stream consideration is a demand fee calculated by multiplying an agreed-on price by a fixed number of volumes per month over a specified term in the contract. Included below is the additional fixed revenue we will earn over the remaining term of the contracts and excludes all variable consideration to be earned with the associated contract. Contract Remaining Term of Contract October - December 2018 2019 2020 2021 2022 Total Remaining Impact to Revenue (In thousands) Demand fee contracts 4-5 years $ 1,299 $ 2,632 $ (3,781 ) $ (3,507 ) $ 1,374 $ (1,983 ) Before implementing ASC 606, we immediately recognized the entire demand fee since the fee was payable within the first five years from the effective date of the contract and not over the entire term of the contract. However, as the demand fee does not specifically relate to a distinct performance obligation, under the new standard that amount should now be recognized over the life of the contract. Therefore, the demand fee previously recognized for $1.7 million ( $1.3 million , net of tax) was adjusted to retained earnings as of January 1, 2018 and will be recognized over the remaining term of the contract. As this amount is fixed, recognition of the remaining portion will be stable. Besides the demand fee, there were no other contract assets or liabilities (see above for the balance sheet line items where they are reported). For the three and nine months ended September 30, 2018 , $1.3 million and $3.7 million , respectively, was recognized in revenue for these demand fees. September 30, January 1, Change (In thousands) Contract assets $ 12,589 $ 10,798 $ 1,791 Contract liabilities 10,605 12,485 (1,880 ) Contract assets (liabilities), net $ 1,984 $ (1,687 ) $ 3,671 Our performance obligations for all contracts is to gather, transport, or process an agreed-on number of volumes as stated in the contract. Typically, the contract will establish a period over which the company will perform the mid-stream services. Certain contracts also include an agreed-on quantity (or an agreed-on minimum quantity) of volumes that the company will deliver or service. The term under mid-stream service contracts is typically five to ten years. Under service contracts, as the customer simultaneously receives and consumes the benefits provided by the entity’s performance as the entity performs, the performance obligation to gather, transport, or process occurs over time. We typically receive payment within a set number of days following the end of the month and includes payment for all services performed that month. Our overall performance obligation is satisfied at the end of the contract term. Most of the consideration received under mid-stream service contracts is variable. The consideration is calculated by multiplying a variable quantity (number of volumes) by an agreed-on price per MCF (commodity fee and the gathering fee). One fixed component of revenue is calculated by multiplying an agreed-on price by a certain volume commitment (MCF per day). Other revenue items may include shortfall fees. All variable consideration is settled at the end of the month; therefore, whether or not the variability is constrained does not affect accounting for revenue under ASC 606 as the variability is known before each reporting period. However, this excludes the shortfall fee as this fee could be based on a set number of volumes over the course of more than one month. Per the new guidance related to disclosures for remaining performance obligations, there is a practical expedient for contracts with an original expected duration of one year or less (ASC 606-10-50-14). There is also a practical expedient for “variable consideration [that] is allocated entirely to a wholly unsatisfied performance obligation… that forms part of a single performance obligation… for which the criteria in paragraph 606-10-32-40 have been met” (ASC 606-10-50-14A). As stated previously, the contract term for mid-stream services is typically longer than one year. However, based on the guidance at 606-10-32-40, we determined some of the variable payment in mid-stream service agreements specifically relates to the entity’s efforts to satisfy the performance obligation and that “allocating the variable amount entirely to the distinct good or service is consistent with the allocation objective in paragraph 606-10-32-28.” Therefore, the practical expedient relates to this variable consideration: the commodity fee and the gathering fee. The last time we received a shortfall fee was in 2016 and the amount was immaterial to total mid-stream revenues. These terms have historically been limited in our contracts. We calculate revenue earned from the variable consideration related to mid-stream services by multiplying the number of volumes serviced times an agreed-on price. Therefore, the variable portion of this consideration is due to the change in volumes. This variability is resolved at the end of each month as the company will know the number of volumes serviced under each contract and payment is received monthly. The mid-stream gathering service contracts remaining are for a duration of less than one year to 15 years. While long term service contracts are in place as of the reporting date, due to the variable volumes an estimation and allocation of transaction price and future obligations are not required.

Divestitures

Divestitures	9 Months Ended
	Sep. 30, 2018
Property, Plant and Equipment Impairment or Disposal [Abstract]
Divestitures	DIVESTITURES Divestitures Oil and Natural Gas We sold non-core oil and natural gas assets, net of related expenses, for $22.3 million during the first nine months of 2018 , compared to $18.0 million during the first nine months of 2017 . Proceeds from those sales reduced the net book value of our full cost pool with no gain or loss recognized. Mid-Stream On April 3, 2018 , we sold 50% of the ownership interest in our mid-stream segment, Superior. The purchaser is SP Investor Holdings, LLC, a holding company jointly owned by OPTrust and funds managed and/or advised by Partners Group, a global private markets investment manager. We received $300.0 million because of this sale. A portion of the proceeds were used to pay down our bank debt and the remainder will accelerate the drilling program of our upstream subsidiary, Unit Petroleum Company, make additional capital investments in the jointly owned Superior, and for general working capital purposes. In connection with the sale of the interest in Superior, we took the necessary actions under the Indenture governing our outstanding senior subordinated notes to secure the ability to close the sale and have Superior released from the Indenture. Superior will be governed and managed under its Amended and Restated Limited Liability Company Agreement and the Master Services and Operating Agreement (MSA) signed by Superior and an affiliate of Unit, as both agreements may be amended occasionally. Further details are in Note 13 – Variable Interest Entity Arrangements.

Earnings Per Share

Earnings Per Share	9 Months Ended
	Sep. 30, 2018
Earnings Per Share [Abstract]
Schedule of Antidilutive Securities Excluded from Computation of Earnings Per Share [Table Text Block]	The following table shows the number of stock options and SARs (and their average exercise price) excluded because their option exercise prices were greater than the average market price of our common stock: Three Months Ended September 30, 2018 2017 Stock options and SARs 66,500 178,755 Average exercise price $ 44.42 $ 47.75 The following table shows the number of stock options and SARs (and their average exercise price) excluded because their option exercise prices were greater than the average market price of our common stock: Nine Months Ended September 30, 2018 2017 Stock options and SARs 66,500 178,755 Average exercise price $ 44.42 $ 47.75
Earnings Per Share	EARNINGS PER SHARE Information related to the calculation of earnings per share attributable to Unit Corporation follows: Earnings (Numerator) Weighted Shares (Denominator) Per-Share Amount (In thousands except per share amounts) For the three months ended September 30, 2018 Basic earnings attributable to Unit Corporation per common share $ 18,899 52,068 $ 0.36 Effect of dilutive stock options and restricted stock — 1,072 — Diluted earnings attributable to Unit Corporation per common share $ 18,899 53,140 $ 0.36 For the three months ended September 30, 2017 Basic earnings attributable to Unit Corporation per common share $ 3,705 51,386 $ 0.07 Effect of dilutive stock options, restricted stock, and stock appreciation rights (SARs) — 586 — Diluted earnings attributable to Unit Corporation per common share $ 3,705 51,972 $ 0.07 The following table shows the number of stock options and SARs (and their average exercise price) excluded because their option exercise prices were greater than the average market price of our common stock: Three Months Ended September 30, 2018 2017 Stock options and SARs 66,500 178,755 Average exercise price $ 44.42 $ 47.75 Earnings (Loss) Weighted Shares (Denominator) Per-Share Amount (In thousands except per share amounts) For the nine months ended September 30, 2018 Basic earnings attributable to Unit Corporation per common share $ 32,552 51,951 $ 0.63 Effect of dilutive stock options and restricted stock — 808 (0.01 ) Diluted earnings attributable to Unit Corporation per common share $ 32,552 52,759 $ 0.62 For the nine months ended September 30, 2017 Basic earnings attributable to Unit Corporation per common share $ 28,693 51,019 $ 0.56 Effect of dilutive stock options, restricted stock, and SARs — 550 — Diluted earnings attributable to Unit Corporation per common share $ 28,693 51,569 $ 0.56 The following table shows the number of stock options and SARs (and their average exercise price) excluded because their option exercise prices were greater than the average market price of our common stock: Nine Months Ended September 30, 2018 2017 Stock options and SARs 66,500 178,755 Average exercise price $ 44.42 $ 47.75

Accrued Liabilities

Accrued Liabilities	9 Months Ended
	Sep. 30, 2018
Accrued Liabilities [Abstract]
Accrued Liabilities	ACCRUED LIABILITIES Accrued liabilities consisted of: September 30, December 31, (In thousands) Employee costs $ 17,880 $ 19,521 Interest payable 17,446 6,745 Lease operating expenses 11,474 11,819 Taxes 10,317 3,404 Derivative settlements 3,383 — Third-party credits 2,099 2,240 Other 5,144 4,794 Total accrued liabilities $ 67,743 $ 48,523

Long-Term Debt And Other Long-T

Long-Term Debt And Other Long-Term Liabilities	9 Months Ended
	Sep. 30, 2018
Debt Disclosure [Abstract]
Long-Term Debt And Other Long-Term Liabilities	LONG-TERM DEBT AND OTHER LONG-TERM LIABILITIES Long-Term Debt Our long-term debt as of the dates indicated consisted of the following: September 30, December 31, (In thousands) Unit credit agreement with an average interest rate of 3.4% at December 31, 2017 $ — $ 178,000 Superior credit agreement — — 6.625% senior subordinated notes due 2021 650,000 650,000 Total principal amount 650,000 828,000 Less: unamortized discount (1,780 ) (2,234 ) Less: debt issuance costs, net (4,299 ) (5,490 ) Total long-term debt $ 643,921 $ 820,276 Unit Credit Agreement. On October 18, 2018, we signed a Fifth Amendment to our Senior Credit Agreement (Unit credit agreement) originally scheduled to mature on April 10, 2020 . The details of this amendment are discussed in Note 17 – Subsequent Events and have not been incorporated into the discussion of the Unit credit agreement immediately below. On April 2, 2018, we entered into a fourth amendment to the Unit credit agreement (Fourth Amendment). The Fourth Amendment provided, among other things, for a reduction of the maximum credit amount from $875.0 million to $425.0 million , a reduction in the borrowing base from $475.0 million to $425.0 million , a reduction in the total commitment amount from $475.0 million to $425.0 million ; and the full release of Superior and its subsidiaries as a borrower and co-obligor under the Unit credit agreement. Under the amendment, once the sale of the interest in Superior was completed, we had to use part of the proceeds to pay down the Unit credit agreement. The Superior sale closed on April 3, 2018 and the pay down was made that day. On May 2, 2018, the company signed a Pledge Agreement with BOKF, NA (dba Bank of Oklahoma), as administrative agent to benefit the secured parties, under which we granted a security interest in the limited liability membership interests and other equity interests we own in Superior (which as of this report is 50% of the aggregate outstanding equity interests of Superior ) as additional collateral for our obligations under the Unit credit agreement. We are charged a commitment fee of 0.50% on the amount available but not borrowed. That fee varies based on the amount borrowed as a percentage of the total borrowing base. We paid $1.0 million in previous origination, agency, syndication, and other related fees. We incurred no additional fees related to the fourth amendment. We are amortizing these fees over the life of the Unit credit agreement. Under the Unit credit agreement, we have pledged as collateral 85% of the proved developed producing (discounted as present worth at 8% ) total value of our oil and gas properties. The borrowing base amount is subject to redetermination by the lenders on April 1st and October 1st of each year and is based on a percentage of the discounted future value of our oil and natural gas reserves. We or the lenders may request a onetime special redetermination of the borrowing base between each scheduled redetermination. In addition, we may request a redetermination following the completion of an acquisition that meets the requirements in the Unit credit agreement. At our election, any part of the outstanding debt under the Unit credit agreement can be fixed at a London Interbank Offered Rate (LIBOR). LIBOR interest is computed as the LIBOR base for the term plus 2.00% to 3.00% depending on the level of debt as a percentage of the borrowing base and is payable at the end of each term, or every 90 days, whichever is less. Borrowings not under LIBOR bear interest at the prime rate specified in the Unit credit agreement but in no event less than LIBOR plus 1.00% plus a margin . Interest is payable at the end of each month and the principal may be repaid in whole or in part at any time, without a premium or penalty. At September 30, 2018 , we had no outstanding borrowings under the Unit credit agreement. We can use borrowings for financing general working capital requirements for (a) exploration, development, production, and acquisition of oil and gas properties, (b) acquisitions and operation of mid-stream assets up to certain limits, (c) issuance of standby letters of credit, (d) contract drilling services and acquisition of contract drilling equipment, and (e) general corporate purposes. The Unit credit agreement prohibits, among other things: • the payment of dividends (other than stock dividends) during any fiscal year over 30% of our consolidated net income for the preceding fiscal year; • the incurrence of additional debt with certain limited exceptions; • the creation or existence of mortgages or liens, other than those in the ordinary course of business and with certain limited exceptions, on any of our properties, except in favor of our lenders; and • investments in Unrestricted Subsidiaries (as defined in the Unit credit agreement) over $200.0 million . Effective September 30, 2018, the Unit credit agreement also requires that we have at the end of each quarter: • a current ratio (as defined in the credit agreement) of not less than 1 to 1 . • a leverage ratio of funded debt to consolidated EBITDA (as defined in the Unit credit agreement) for the most recently ended rolling four fiscal quarters of no greater than 4 to 1 . As of September 30, 2018, we were in compliance with the Unit credit agreement covenants. Superior Credit Agreement. On May 10, 2018 , Superior signed a five -year, $200.0 million senior secured revolving credit facility with an option to increase the credit amount up to $250.0 million , subject to certain conditions (Superior credit agreement). The amounts borrowed under the Superior credit agreement bear annual interest at a rate, at Superior’s option, equal to (a) LIBOR plus the applicable margin of 2.00% to 3.25% or (b) the alternate base rate (greater of (i) the federal funds rate plus 0.5%, (ii) the prime rate, and (iii) third day LIBOR plus 1.00%) plus the applicable margin of 1.00% to 2.25%. The obligations under the Superior credit agreement are secured by, among other things, mortgage liens on certain of Superior’s processing plants and gathering systems. Superior is charged a commitment fee of 0.375% on the amount available but not borrowed which varies based on the amount borrowed as a percentage of the total borrowing base. Superior paid $1.7 million in origination, agency, syndication, and other related fees. These fees are being amortized over the life of the Superior credit agreement. The Superior credit agreement requires that Superior maintain a Consolidated EBITDA to interest expense ratio for the most-recently ended rolling four quarters of at least 2.50 to 1.00 , and a funded debt to Consolidated EBITDA ratio of not greater than 4.00 to 1.00 . The Superior credit agreement also contains several customary covenants that restrict (subject to certain exceptions) Superior’s ability to incur additional indebtedness, create additional liens on its assets, make investments, pay distributions, sign sale and leaseback transactions, engage in certain transactions with affiliates, engage in mergers or consolidations, sign hedging arrangements, and acquire or dispose of assets. As of September 30, 2018, Superior was in compliance with the Superior credit agreement covenants. The borrowings under the Superior credit agreement will fund capital expenditures and acquisitions, provide general working capital, and for letters of credit for Superior. On June 27, 2018, Superior and the lenders amended the Superior credit agreement to revise certain definitions in the agreement. Superior's credit agreement is not guaranteed by Unit. 6.625% Senior Subordinated Notes. We have an aggregate principal amount of $650.0 million , 6.625% senior subordinated notes (the Notes) outstanding. Interest on the Notes is payable semi-annually (in arrears) on May 15 and November 15 of each year. The Notes mature on May 15, 2021 . In issuing the Notes, we incurred fees of $14.7 million that are being amortized as debt issuance cost over the life of the Notes. The Notes are subject to an Indenture dated as of May 18, 2011, between us and Wilmington Trust, National Association (successor to Wilmington Trust FSB), as Trustee (the Trustee), as supplemented by the First Supplemental Indenture dated as of May 18, 2011, between us, the Guarantors, and the Trustee, and as further supplemented by the Second Supplemental Indenture dated as of January 7, 2013, between us, the Guarantors, and the Trustee (as supplemented, the 2011 Indenture), establishing the terms of and providing for issuing the Notes. The Guarantors are most of our direct and indirect subsidiaries. The discussion of the Notes in this report is qualified by and subject to the actual terms of the 2011 Indenture. Unit, as the parent company, has no significant independent assets or operations. The guarantees by the Guarantors of the Notes (registered under registration statements) are full and unconditional, joint and several, subject to certain automatic customary releases, are subject to certain restrictions on the sale, disposition, or transfer of the capital stock or substantially all of the assets of a subsidiary guarantor, and other conditions and terms set out in the 2011 Indenture. Effective April 3, 2018, Superior is no longer a Guarantor of the Notes. Any of our other subsidiaries that are not Guarantors are minor. There are no significant restrictions on our ability to receive funds from any of our subsidiaries through dividends, loans, advances, or otherwise. We may redeem all or, occasionally, a part of the Notes at certain redemption prices, plus accrued and unpaid interest. If a “change of control” occurs, subject to certain conditions, we must offer to repurchase from each holder all or any part of that holder’s Notes at a purchase price in cash equal to 101% of the principal amount of the Notes plus accrued and unpaid interest to the date of purchase. The 2011 Indenture contains customary events of default. The 2011 Indenture also contains covenants including those that limit our ability and the ability of certain of our subsidiaries to incur or guarantee additional indebtedness; pay dividends on our capital stock or redeem capital stock or subordinated indebtedness; transfer or sell assets; make investments; incur liens; enter into transactions with our affiliates; and merge or consolidate with other companies. We were in compliance with all covenants of the Notes as of September 30, 2018 . Other Long-Term Liabilities Other long-term liabilities consisted of the following: September 30, December 31, (In thousands) Asset retirement obligation (ARO) liability $ 62,727 $ 69,444 Workers’ compensation 12,832 13,340 Capital lease obligations 12,355 15,224 Contract liability 10,605 — Separation benefit plans 8,135 6,524 Deferred compensation plan 5,623 5,390 Gas balancing liability 3,283 3,283 115,560 113,205 Less current portion 14,150 13,002 Total other long-term liabilities $ 101,410 $ 100,203 Estimated annual principal payments under the terms of our long-term debt and other long-term liabilities during the five successive twelve-month periods beginning October 1, 2018 (and through 2023) are $14.1 million , $43.1 million , $659.8 million , $4.6 million , and $2.3 million , respectively. Capital Leases In 2014, Superior entered into capital lease agreements for 20 compressors with initial terms of seven years. The underlying assets are included in gas gathering and processing equipment. The $4.0 million current portion of the capital lease obligations is included in current portion of other long-term liabilities and the non-current portion of $8.4 million is included in other long-term liabilities in the accompanying Unaudited Condensed Consolidated Balance Sheets as of September 30, 2018 . These capital leases are discounted using annual rates of 4.00% . Total maintenance and interest remaining related to these leases are $4.6 million and $0.8 million , respectively, at September 30, 2018 . Annual payments, net of maintenance and interest, average $4.2 million annually through 2021 . At the end of the term, Superior has the option to purchase the assets at 10% of their then fair market value. Future payments required under the capital leases at September 30, 2018 are: Amount Beginning October 1, (In thousands) 2018 $ 6,195 2019 6,195 2020 5,322 Total future payments 17,712 Less payments related to: Maintenance 4,601 Interest 756 Present value of future minimum payments $ 12,355

Asset Retirement Obligations

Asset Retirement Obligations	9 Months Ended
	Sep. 30, 2018
Asset Retirement Obligation Disclosure [Abstract]
Asset Retirement Obligations	ASSET RETIREMENT OBLIGATIONS We are required to record the estimated fair value of the liabilities relating to the future retirement of our long-lived assets. Our oil and natural gas wells are plugged and abandoned when the oil and natural gas reserves in those wells are depleted or the wells are no longer able to produce. The plugging and abandonment liability for a well is recorded in the period in which the obligation is incurred (at the time the well is drilled or acquired). None of our assets are restricted for purposes of settling these AROs. All our AROs relate to the plugging costs associated with our oil and gas wells. The following table shows certain information about our AROs for the periods indicated: Nine Months Ended September 30, 2018 2017 (In thousands) ARO liability, January 1: $ 69,444 $ 70,170 Accretion of discount 1,829 2,112 Liability incurred 244 1,123 Liability settled (3,907 ) (1,350 ) Liability sold (105 ) (1,563 ) Revision of estimates (1) (4,778 ) 4,993 ARO liability, September 30: 62,727 75,485 Less current portion 1,451 2,947 Total long-term ARO $ 61,276 $ 72,538 _______________________ (1) Plugging liability estimates were revised in both 2018 and 2017 for updates in the cost of services used to plug wells over the preceding year. We had various upward and downward adjustments.

New Accounting Pronouncements

New Accounting Pronouncements	9 Months Ended
	Sep. 30, 2018
New Accounting Pronouncements and Changes in Accounting Principles [Abstract]
New Accounting Pronouncements	NEW ACCOUNTING PRONOUNCEMENTS Fair Value Measurement (Topic 820): Disclosure Framework—Changes to the Disclosure Requirements for Fair Value Measurement. The FASB issued ASU 2018-13 to modify the disclosure requirements in Topic 820. Part of the disclosures were removed or modified and other disclosures were added. The amendment will be effective for reporting periods beginning after December 15, 2019. Early adoption is permitted. Also it is permitted to early adopt any removed or modified disclosure and delay adoption of the additional disclosures until their effective date. This amendment will not have a material impact on our financial statements. Compensation—Stock Compensation: Improvements to Nonemployee Share-Based Payment Accounting. The FASB issued ASU 2018-07, to improve financial reporting for nonemployee share-based payments. The amendment expands Topic 718, Compensation—Stock Compensation to include share-based payments issued to nonemployees for goods or services. The amendment will be effective for years beginning after December 15, 2019, and interim periods within those years. This amendment will not have a material impact on our financial statements. Income Taxes - Amendments to SEC Paragraphs Pursuant to SEC Staff Accounting Bulletin No. 118. In March 2018, the FASB issued ASU 2018-05 which updates the FASB’s Accounting Standards Codification to reflect the guidance in SAB 118, which adds Section EE, “Income Tax Accounting Implications of the Tax Cuts and Jobs Act,” to SAB Topic 5, “Miscellaneous Accounting.” SAB 118 also provides guidance on applying ASC 740, Income Taxes, if the accounting for certain income tax effects of the Tax Cuts and Jobs Act of 2017 is incomplete when the financial statements are issued for a reporting period. Intangibles—Goodwill and Other: Simplifying the Test for Goodwill Impairment. The FASB issued ASU 2017-04, to simplify the measurement of goodwill. The amendment eliminates Step 2 from the goodwill impairment test. The amendment will be effective prospectively for reporting periods beginning after December 15, 2019, and early adoption is permitted. This amendment will not have a material impact on our financial statements. Leases. The FASB has issued several accounting standards updates and amendments related to leases in the past two years, which are codified within Topic 842. For public companies, these are effective for annual periods beginning after December 15, 2018, and interim periods within those annual periods. The standard requires lessees to recognize at the commencement date of a lease a lease liability, which represents the lessee's obligation to make lease payments arising from the lease, measured on a discounted basis; and a right-of-use asset, which represents the lessee's right to use a specified asset for the lease term. Other recently issued amendments to Topic 842 have provided clarifying guidance regarding land easements, an additional modified retrospective transition method, and added several practical expedients to apply Topic 842 for both lessees and lessors. The standard will not apply to leases of mineral rights. We have an implementation team working through the provisions of the new guidance including a review of different types of contracts to document our lease portfolio and assess the impact on our accounting, disclosures, processes, internal control over financial reporting, and the election of certain practical expedients. Our evaluation of the impact of the new guidance on our financial statements is on-going. We have made certain accounting policy decisions including that we plan to adopt the short-term lease recognition exemption, accounting for certain asset classes at a portfolio level, and establishing a balance sheet recognition capitalization threshold. Our transition will utilize the modified retrospective approach to adopting the new standard, and will be applied at the beginning of the period adopted (January 1, 2019) in accordance with ASU 2018-11. We expect to elect the transition practical expedient, which allows us to not evaluate land easements that existed prior to January 1, 2019, and the optional transition method to record the adoption impact through a cumulative adjustment to equity. We expect for certain lessee asset classes to elect the practical expedient and not separate lease and nonlease components. For these asset classes, we will account for the agreements as a single lease component. We expect for certain lessor asset classes to elect the practical expedient and not separate lease and nonlease components and determine the appropriate accounting based on the predominate component of the contract. The assessment of predominance is ongoing. We anticipate a material impact to the balance sheet across segments as we recognize Right of Use assets and liabilities but no material impact to the income statement (from the lessee's perspective). The assessment of the dollar value impact of adoption is on-going. Adopted Standards Reclassification of Certain Tax Effects from Accumulated Other Comprehensive Income. The FASB issued ASU 2018-02, an amendment which provides financial statement preparers with an option to reclassify stranded tax effects within AOCI to retained earnings caused by the Tax Cuts and Jobs Act of 2017. The amendment is effective for fiscal years beginning after December 15, 2018, and interim periods within those fiscal years. Early adoption is permitted. Organizations should apply the proposed amendments either in the period of adoption or retrospectively to each period (or periods) in which the effect of the change in the U.S. federal corporate income tax rate in the Tax Cuts and Jobs Act is recognized. We adopted this amendment early and it had no material effect to our financial statements. We previously used 37.75% to calculate the tax effect on AOCI and now we are using 24.5%. The change is reflected in our Unaudited Condensed Consolidated Statements of Comprehensive Income and in Note 14 - Equity. Revenue from Contracts with Customers. Effective January 1, 2018, we adopted ASC 606. This new revenue standard provides for a five-step analysis of transactions to determine when and how revenue is to be recognized. The guidance in this update supersedes the revenue recognition requirements in ASC 605, Revenue Recognition, and most industry-specific guidance throughout the Industry Topics of the Codification. Under the standard, revenue is recognized when a customer obtains control of promised goods or services in an amount that reflects the consideration the entity expects to receive in exchange for those goods or services. In addition, the standard requires disclosure of the nature, amount, timing, and uncertainty of revenue and cash flows arising from contracts with customers. We applied the five-step method outlined in the ASU to all our revenue streams in the scope of ASC 606 and elected the modified retrospective approach method. Under that approach the cumulative effect on adoption is recognized as an adjustment to opening retained earnings at January 1, 2018. Only our mid-stream segment was affected. This adjustment related to the timing of revenue on certain demand fees. Both our oil and natural gas and contract drilling segments had no retained earnings adjustment. Comparative prior periods have not been adjusted and continue to be reported under ASC 605. The additional disclosures required by ASC 606 have been included in Note 2 – Revenue from Contracts with Customers. Our internal control framework did not materially change because of this standard, but the existing internal controls have been modified to consider our new revenue recognition policy effective January 1, 2018. As we implement the new standard, we have added internal controls to ensure that we adequately evaluate new contracts under the five-step model under ASU 2014-09.

Stock-Based Compensation

Stock-Based Compensation	9 Months Ended
	Sep. 30, 2018
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]
Stock-Based Compensation	STOCK-BASED COMPENSATION For restricted stock awards and stock options, we had: Three Months Ended Nine Months Ended September 30, September 30, 2018 2017 2018 2017 (In millions) Recognized stock compensation expense $ 4.1 $ 3.2 $ 13.6 $ 9.0 Capitalized stock compensation cost for our oil and natural gas properties 0.6 0.5 1.6 1.3 Tax benefit on stock-based compensation 1.0 1.2 3.3 3.4 The remaining unrecognized compensation cost related to unvested awards at September 30, 2018 is approximately $19.0 million , of which $2.4 million is anticipated to be capitalized. The weighted average period over which this cost will be recognized is 1.0 year . Our Second Amended and Restated Unit Corporation Stock and Incentive Compensation Plan effective May 6, 2015 (the amended plan) allows us to grant stock-based and cash-based compensation to our employees (including employees of subsidiaries) and to non-employee directors. 7,230,000 shares of the company's common stock are authorized for issuance to eligible participants under the amended plan with 2,000,000 shares being the maximum number of shares that can be issued as "incentive stock options." We granted no SARs or stock options during either of the three or nine month periods ending September 30, 2018 or 2017 . We did not grant any restricted stock awards during either of the three month periods ending September 30, 2018 or 2017 . This table shows the fair value of restricted stock awards granted to employees and non-employee directors during the periods indicated: Nine Months Ended Nine Months Ended September 30, 2018 September 30, 2017 Time Vested Performance Vested Time Vested Performance Vested Shares granted: Employees 844,498 362,070 475,799 173,373 Non-employee directors 44,312 — 49,104 — 888,810 362,070 524,903 173,373 Estimated fair value (in millions): (1) Employees $ 16.2 $ 7.3 $ 11.8 $ 4.5 Non-employee directors 0.9 — 0.9 — $ 17.1 $ 7.3 $ 12.7 $ 4.5 Percentage of shares granted expected to be distributed: Employees 95 % 74 % 95 % 91 % Non-employee directors 100 % N/A 100 % N/A _______________________ (1) The performance shares represent 100% of the grant date fair value. (We recognize the grant date fair value minus estimated forfeitures.) The time vested restricted stock awards granted during the first nine months of 2018 and 2017 are being recognized over a three -year vesting period. During the first quarter of 2018 and 2017, two performance vested restricted stock awards were granted to certain executive officers. The first will cliff vest three years from the grant date based on the company's achievement of certain stock performance measures (TSR) at the end of the term and will range from 0% to 200% of the restricted shares granted as performance shares. The second will vest, one-third each year, over a three -year vesting period subject to the company's achievement of cash flow to total assets (CFTA) performance measurement each year and will range from 0% to 200% . Based on a probability assessment of the selected TSR performance criteria at September 30, 2018 , the participants are estimated to receive 49% of the 2018, 92% of the 2017, and 170% of the 2016 performance-based shares. The CFTA performance measurement at September 30, 2018 was assessed to vest at target or 100% . The total aggregate stock compensation expense and capitalized cost related to oil and natural gas properties for 2018 awards for the first nine months of 2018 was $7.5 million .

Derivatives

Derivatives	9 Months Ended
	Sep. 30, 2018
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Derivatives	DERIVATIVES Commodity Derivatives We have signed various types of derivative transactions covering some of our projected natural gas and oil production. These transactions are intended to reduce our exposure to market price volatility by setting the price(s) we will receive for that production. Our decisions on the price(s), type, and quantity of our production subject to a derivative contract are based, in part, on our view of current and future market conditions. As of September 30, 2018 , these hedges made up our derivative transactions: • Swaps. We receive or pay a fixed price for the commodity and pay or receive a floating market price to the counterparty. The fixed-price payment and the floating-price payment are netted, resulting in a net amount due to or from the counterparty. • Basis/Differential Swaps. We receive or pay the NYMEX settlement value plus or minus a fixed delivery point price for the commodity and pay or receive the published index price at the specified delivery point. We use basis/differential swaps to hedge the price risk between NYMEX and its physical delivery points. • Collars. A collar contains a fixed floor price (put) and a ceiling price (call). If the market price exceeds the call strike price or falls below the put strike price, we receive the fixed price and pay the market price. If the market price is between the call and the put strike price, no payments are due from either party. • Three-way collars. A three-way collar contains a fixed floor price (long put), fixed subfloor price (short put), and a fixed ceiling price (short call). If the market price exceeds the ceiling strike price, we receive the ceiling strike price and pay the market price. If the market price is between the ceiling and the floor strike price, no payments are due from either party. If the market price is below the floor price but above the subfloor price, we receive the floor strike price and pay the market price. If the market price is below the subfloor price, we receive the market price plus the difference between the floor and subfloor strike prices and pay the market price. We have documented policies and procedures to monitor and control the use of derivative transactions. We do not engage in derivative transactions not otherwise tied to our projected production. Any changes in the fair value of our derivative transactions before maturity (i.e., temporary fluctuations in value) are reported in gain (loss) on derivatives in our Unaudited Condensed Consolidated Income Statements. At September 30, 2018 , these derivatives were outstanding: Term Commodity Contracted Volume Weighted Average Fixed Price Contracted Market Oct'18 Natural gas – swap 30,000 MMBtu/day $3.005 IF – NYMEX (HH) Nov’18 – Dec'18 Natural gas – swap 20,000 MMBtu/day $3.013 IF – NYMEX (HH) Jan'19 – Dec'19 Natural gas – swap 10,000 MMBtu/day $2.810 IF – NYMEX (HH) Oct'18 Natural gas – basis swap 10,000 MMBtu/day $(0.190) NGPL TEXOK Oct'18 – Dec'18 Natural gas – basis swap 10,000 MMBtu/day $(0.678) PEPL Oct'18 – Dec'18 Natural gas – basis swap 10,000 MMBtu/day $(0.568) NGPL MIDCON Nov’18 – Dec'18 Natural gas – basis swap 10,000 MMBtu/day $(0.208) IF – NYMEX (HH) Jan'19 – Dec'19 Natural gas – basis swap 20,000 MMBtu/day $(0.659) PEPL Jan'19 – Dec'19 Natural gas – basis swap 10,000 MMBtu/day $(0.625) NGL MIDCON Jan'19 – Dec'19 Natural gas – basis swap 30,000 MMBtu/day $(0.265) NGPL TEXOK Jan'20 – Dec'20 Natural gas – basis swap 30,000 MMBtu/day $(0.275) NGPL TEXOK Oct'18 – Dec'18 Natural gas – three-way collar 20,000 MMBtu/day $3.00 - $2.50 - $3.51 IF – NYMEX (HH) Oct'18 – Dec'18 Crude oil – swap 4,000 Bbl/day $53.52 WTI – NYMEX Oct'18 – Dec'18 Crude oil – price differential risk 500 Bbl/day $7.00 LLS/WTI Oct'18 – Dec'18 Crude oil – three-way collar 2,000 Bbl/day $47.50 - $37.50 - $56.08 WTI – NYMEX Jan'19 – Dec'19 Crude oil – three-way collar 4,000 Bbl/day $61.25 - $51.25 - $72.93 WTI – NYMEX After September 30, 2018 , the following derivatives were entered into: Term Commodity Contracted Volume Weighted Average Fixed Price Contracted Market Jan'19 – Dec'19 Natural gas – swap 10,000 MMBtu/day $2.850 IF – NYMEX (HH) Jan'19 – Dec'19 Natural gas – collar 20,000 MMBtu/day $2.63 - $3.03 IF – NYMEX (HH) Jan'19 – Mar'19 Natural gas – three-way collar 10,000 MMBtu/day $3.00 - $2.75 - $4.35 IF – NYMEX (HH) The following tables present the fair values and locations of the derivative transactions recorded in our Unaudited Condensed Consolidated Balance Sheets: Derivative Assets Fair Value Balance Sheet Location September 30, December 31, (In thousands) Commodity derivatives: Current Current derivative asset $ — $ 721 Long-term Non-current derivative asset — — Total derivative assets $ — $ 721 Derivative Liabilities Fair Value Balance Sheet Location September 30, December 31, (In thousands) Commodity derivatives: Current Current derivative liability $ 13,067 $ 7,763 Long-term Non-current derivative liability 1,542 — Total derivative liabilities $ 14,609 $ 7,763 All our counterparties are subject to master netting arrangements. If we have a legal right of set-off, we net the value of the derivative transactions we have with the same counterparty in our Unaudited Condensed Consolidated Balance Sheets. Following is the effect of derivative instruments on the Unaudited Condensed Consolidated Income Statements for the three months ended September 30 : Derivatives Instruments Location of Gain (Loss) Recognized in Income on Derivative Amount of Gain (Loss) Recognized in Income on Derivative 2018 2017 (In thousands) Commodity derivatives Loss on derivatives (1) $ (4,385 ) $ (2,614 ) Total $ (4,385 ) $ (2,614 ) _______________________ (1) Amounts settled during the 2018 and 2017 periods include net payments of $9.1 million and net proceeds of $0.8 million , respectively. Following is the effect of derivative instruments on the Unaudited Condensed Consolidated Income Statements for the nine months ended September 30 : Derivatives Instruments Location of Gain (Loss) Recognized in Income on Derivative Amount of Gain (Loss) Recognized in Income on Derivative 2018 2017 (In thousands) Commodity derivatives Gain (loss) on derivatives (1) $ (25,608 ) $ 21,019 Total $ (25,608 ) $ 21,019 _______________________ (1) Amounts settled during the 2018 and 2017 periods include net payments of $18.0 million and $0.7 million , respectively.

Fair Value Measurements

Fair Value Measurements	9 Months Ended
	Sep. 30, 2018
Fair Value Disclosures [Abstract]
Fair Value Measurements	FAIR VALUE MEASUREMENTS The estimated fair value of our available-for-sale securities, reflected on our Unaudited Condensed Consolidated Balance Sheets as Non-current other assets, is based on market quotes. The following is a summary of available-for-sale securities: Cost Gross Unrealized Gains Gross Unrealized Losses Estimated Fair Value (In thousands) Equity Securities: September 30, 2018 $ 830 $ — $ 137 $ 693 December 31, 2017 $ 830 $ 102 $ — $ 932 During the second quarter of 2017, we received available-for-sale securities for early termination fees associated with a long-term drilling contract. We will evaluate the marketability of those equity securities to determine if any decline in fair value below cost is other-than-temporary. If a decline in fair value below cost is determined to be other-than-temporary, an impairment charge will be recorded, and a new cost basis established. We will review several factors to determine whether a loss is other-than-temporary. These factors include, but are not limited to, (i) the time a security is in an unrealized loss position, (ii) the extent to which fair value is less than cost, (iii) the financial condition and near-term prospects of the issuer, and (iv) our intent and ability to hold the security for a period of time sufficient to allow for any anticipated recovery in fair value. Fair value is defined as the amount that would be received from the sale of an asset or paid for transferring a liability in an orderly transaction between market participants (in either case, an exit price). To estimate an exit price, a three-level hierarchy is used prioritizing the valuation techniques used to measure fair value into three levels with the highest priority given to Level 1 and the lowest priority given to Level 3. The levels are summarized as follows: • Level 1—unadjusted quoted prices in active markets for identical assets and liabilities. • Level 2—significant observable pricing inputs other than quoted prices included within level 1 either directly or indirectly observable as of the reporting date. Essentially, inputs (variables used in the pricing models) that are derived principally from or corroborated by observable market data. • Level 3—generally unobservable inputs developed based on the best information available and may include our own internal data. The inputs available to us determine the valuation technique we use to measure the fair values of our financial instruments. The following tables set forth our recurring fair value measurements: September 30, 2018 Level 1 Level 2 Level 3 Effect of Netting Net Amounts Presented (In thousands) Financial assets (liabilities): Commodity derivatives: Assets $ — $ 1,282 $ 88 $ (1,370 ) $ — Liabilities — (8,372 ) (7,607 ) 1,370 (14,609 ) Total commodity derivatives — (7,090 ) (7,519 ) — (14,609 ) Equity securities 693 — — — 693 $ 693 $ (7,090 ) $ (7,519 ) $ — $ (13,916 ) December 31, 2017 Level 1 Level 2 Level 3 Effect of Netting Net Amounts Presented (In thousands) Financial assets (liabilities): Commodity derivatives: Assets $ — $ 2,137 $ 3,344 $ (4,760 ) $ 721 Liabilities — (8,973 ) (3,550 ) 4,760 (7,763 ) Total commodity derivatives $ — $ (6,836 ) $ (206 ) $ — $ (7,042 ) Equity securities 932 — — — 932 $ 932 $ (6,836 ) $ (206 ) $ — $ (6,110 ) All our counterparties are subject to master netting arrangements. If a legal right of set-off exists, we net the value of the derivative transactions we have with the same counterparty. We are not required to post cash collateral with our counterparties and no collateral has been posted as of September 30, 2018 . We used the following methods and assumptions to estimate the fair values of the assets and liabilities in the table above. There were no transfers between Level 2 and Level 3 financial assets (liabilities). Level 1 Fair Value Measurements Equity Securities. We measure the fair values of our available for sale securities based on market quotes. Level 2 Fair Value Measurements Commodity Derivatives . We measure the fair values of our crude oil and natural gas swaps using estimated internal discounted cash flow calculations based on the NYMEX futures index. Level 3 Fair Value Measurements Commodity Derivatives . The fair values of our natural gas and crude oil collars and three-way collars are estimated using internal discounted cash flow calculations based on forward price curves, quotes obtained from brokers for contracts with similar terms, or quotes obtained from counterparties to the agreements. The following table is a reconciliation of our level 3 fair value measurements: Net Derivatives Three Months Ended Nine Months Ended September 30, September 30, 2018 2017 2018 2017 (In thousands) Beginning of period $ (6,135 ) $ 4,093 $ (206 ) $ (7,122 ) Total gains or losses (realized and unrealized): Included in earnings (1) (3,700 ) (2,015 ) (12,324 ) 9,102 Settlements 2,316 (592 ) 5,011 (494 ) End of period $ (7,519 ) $ 1,486 $ (7,519 ) $ 1,486 Total gains (losses) for the period included in earnings attributable to the change in unrealized gain relating to assets still held at end of period $ (1,384 ) $ (2,607 ) $ (7,313 ) $ 8,608 _______________________ (1) Commodity derivatives are reported in the Unaudited Condensed Consolidated Income Statements in gain (loss) on derivatives. The following table provides quantitative information about our Level 3 unobservable inputs at September 30, 2018 : Commodity (1) Fair Value Valuation Technique Unobservable Input Range (In thousands) Oil three-way collars $ (7,607 ) Discounted cash flow Forward commodity price curve $0 - $17.65 Natural gas three-way collars $ 88 Discounted cash flow Forward commodity price curve $0 - $0.12 _______________________ (1) The commodity contracts detailed in this category include non-exchange-traded crude oil and natural gas three-way collars that are valued based on NYMEX. The forward pricing range represents the low and high price expected to be paid or received within the settlement period. Our valuation at September 30, 2018 reflected that the risk of non-performance was immaterial. Fair Value of Other Financial Instruments This disclosure of the estimated fair value of financial instruments is made under accounting guidance for financial instruments. We have determined the estimated fair values by using market information and valuation methodologies. Considerable judgment is required in interpreting market data to develop the estimates of fair value. Using different market assumptions or valuation methodologies may have a material effect on the estimated fair value amounts. At September 30, 2018 , the carrying values on the Unaudited Condensed Consolidated Balance Sheets for cash and cash equivalents (composed of bank and money market accounts - classified as Level 1), accounts receivable, accounts payable, other current assets, and current liabilities approximate their fair value because of their short-term nature. Based on the borrowing rates available to us for credit agreement debt with similar terms and maturities and considering the risk of our non-performance, long-term debt under our credit agreements approximate their fair value and at September 30, 2018 we did no t have any outstanding borrowings under either the Unit or Superior credit agreement. Borrowings from our Unit credit agreement at December 31, 2017 were $178.0 million . These borrowings would be classified as Level 2. The carrying amounts of long-term debt associated with the Notes, net of unamortized discount and debt issuance costs, reported in the Unaudited Condensed Consolidated Balance Sheets as of September 30, 2018 and December 31, 2017 were $643.9 million and $642.3 million , respectively. We estimate the fair value of the Notes using quoted marked prices at September 30, 2018 and December 31, 2017 was $655.5 million and $649.7 million , respectively. The Notes would be classified as Level 2. Fair Value of Non-Financial Instruments The initial measurement of AROs at fair value is calculated using discounted cash flow techniques and based on internal estimates of future retirement costs associated with property, plant, and equipment. Significant Level 3 inputs used in the calculation of AROs include plugging costs and remaining reserve lives. A reconciliation of the company’s AROs is presented in Note 7 – Asset Retirement Obligations.

Commitments and Contingencies

Commitments and Contingencies	9 Months Ended
	Sep. 30, 2018
Commitments and Contingencies [Abstract]
Commitments and Contingencies	COMMITMENTS AND CONTINGENCIES We lease office space or yards in Edmond and Oklahoma City, Oklahoma; Houston, Texas; Englewood, Colorado; Pinedale, Wyoming; and Canonsburg, Pennsylvania under the terms of operating leases expiring through December 2021. We own our corporate headquarters in Tulsa, Oklahoma. We also have several compressor rentals, equipment leases, and lease space on short-term commitments to stack excess drilling rig equipment and production inventory. Future minimum rental payments under the terms of the leases are approximately $5.1 million , $2.1 million , $0.6 million , and less than $0.1 million in twelve-month periods beginning October 1, 2018 (and through 2021), respectively. Total rent expense incurred was $7.2 million and $6.4 million for the first nine months of 2018 and 2017 , respectively. In 2014, Superior signed capital lease agreements for 20 compressors with initial terms of seven years. Estimated annual capital lease payments under the terms during the four successive twelve-month periods beginning October 1, 2018 (and through the end of 2021) are $6.2 million , $6.2 million , and $5.3 million . Total maintenance and interest remaining related to these leases are $4.6 million and $0.8 million , respectively at September 30, 2018 . Annual payments, net of maintenance and interest, average $4.2 million annually through 2021 . At the end of the term, Superior has the option to purchase the assets at 10% of their then fair market value. The employee oil and gas limited partnerships require, on the election of a limited partner, that we repurchase the limited partner’s interest at amounts to be determined by appraisal. In any one year, these repurchases are limited to 20% of the units outstanding. We made repurchases of approximately $1,700 and $2,900 in the first nine months of 2018 and 2017, respectively. We manage our exposure to environmental liabilities on properties to be acquired by identifying existing problems and assessing the potential liability. We also conduct periodic reviews, on a company-wide basis, to identify changes in our environmental risk profile. These reviews evaluate whether there is a probable liability, its amount, and the likelihood that the liability will be incurred. Any potential liability is determined by considering, among other matters, incremental direct costs of any likely remediation and the proportionate cost of employees expected to devote significant time directly to any possible remediation effort. As it relates to evaluations of purchased properties, depending on the extent of an identified environmental problem, we may exclude a property from the acquisition, require the seller to remediate the property to our satisfaction, or agree to assume liability for the remediation of the property. We have not historically experienced any environmental liability while being a contract driller since the greatest portion of risk is borne by the operator. Any liabilities we have incurred have been small and have been resolved while the drilling rig is on the location and the cost has been included in the direct cost of drilling the well. During the second quarter of 2018, as part of the Superior transaction, we entered into a contractual obligation that commits us to spend $150.0 million to drill wells in the Granite Wash/Buffalo Wallow area over three years starting January 1, 2019. This amount is already included in our drilling plan. For each dollar of the $150.0 million that we do not spend (over the three year period), we would forgo receiving $0.58 of future distributions from our 50% ownership interest in our consolidated mid-stream subsidiary. If we elected not to drill or spend any money in the designated area over the three year period, the maximum amount we could forgo from distributions would be $87.0 million. For the next twelve months, we have committed to purchase approximately $10.1 million of new drilling rig components.

Variable Interest Entity Arrang

Variable Interest Entity Arrangements	9 Months Ended
	Sep. 30, 2018
Variable Interest Entity Arrangements [Abstract]
Variable Interest Entity Arrangements	VARIABLE INTEREST ENTITY ARRANGEMENTS On April 3, 2018 we sold 50% of the ownership interest in Superior. The 50% interest in Superior we sold was acquired by SP Investor Holdings, LLC, a holding company jointly owned by OPTrust and funds managed and/or advised by Partners Group, a global private markets investment manager. Superior will be governed and managed under the Amended and Restated Limited Liability Company Agreement and the MSA. The MSA is between our affiliate, SPC Midstream Operating, L.L.C. (the Operator) and Superior. The Operator is owned 100% by Unit Corporation. Under the guidance in ASC 810, Consolidation, we have determined that Superior is a VIE. The two variable interests applicable to Unit include the 50% equity investment in Superior and the MSA. The MSA houses the power to direct the activities that most significantly impact Superior's operating performance. The MSA is a separate variable interest. Unit through the MSA has the power to direct Superior’s most significant activities; reciprocally the equity investors lack the power to direct the activities that most significantly impact the entity’s economic performance. Because of this, Unit is considered the primary beneficiary. There have been no changes to the primary beneficiary during the quarter ended September 30, 2018. As the primary beneficiary of this VIE, we consolidate in the financial statements the financial position, results of operations and cash flows of this VIE, and all intercompany balances and transactions between us and the VIE are eliminated in the consolidated financial statements. Cash distributions of income, net of agreed on expenses, and estimated expenses are allocated to the equity owners as specified in the relevant agreements. On the sale or liquidation of Superior, distributions would occur in the order and priority specified in the relevant agreements. As the Operator, we provide services, such as operations and maintenance support, accounting, legal, and human resources to Superior for a monthly service fee of $250,000 . Superior's creditors have no recourse to our general credit. Superior's credit agreement is not guaranteed by Unit. The obligations under Superior's credit agreement are secured by, among other things, mortgage liens on certain of Superior’s processing plants and gathering systems. The carrying value of Superior's assets and liabilities, after eliminations of any intercompany transactions and balances, in the consolidated balance sheets were as follows: September 30, (In thousands) Current assets: Cash and cash equivalents $ 9,039 Accounts receivable 29,991 Prepaid expenses and other 2,756 Total current assets 41,786 Property and equipment: Gas gathering and processing equipment 751,715 Transportation equipment 3,064 754,779 Less accumulated depreciation, depletion, amortization, and impairment 353,476 Net property and equipment 401,303 Other assets 15,411 Total assets $ 458,500 Current liabilities: Accounts payable $ 28,183 Accrued liabilities 3,574 Current portion of other long-term liabilities 6,836 Total current liabilities 38,593 Long-term debt less debt issuance costs — Other long-term liabilities 16,126 Total liabilities $ 54,719

Equity

Equity	9 Months Ended
	Sep. 30, 2018
Equity [Abstract]
Equity	EQUITY At-the-Market (ATM) Common Stock Program On April 4, 2017, we signed a Distribution Agreement (the Agreement) with a sales agent, under which we could offer and sell, from time to time, through the sales agent shares of our common stock, par value $.20 per share (the Shares), up to an aggregate offering price of $100.0 million . Net proceeds from any of these sales could be used to fund (or offset costs of) acquisitions, future capital expenditures, repay amounts outstanding under our revolving credit facility, and general corporate purposes. On May 2, 2018, we terminated the Distribution Agreement. The Distribution Agreement was terminable at will on written notification by us with no penalty. As of the date of termination, we had sold 787,547 shares of our common stock under the Distribution Agreement resulting in net proceeds of approximately $18.6 million . We paid the sales agent a commission of 2.0% of the gross sales price per share sold. As a result of the termination, there will be no more sales of our common stock under the Distribution Agreement. Accumulated Other Comprehensive Income (Loss) Components of accumulated other comprehensive income (loss) were as follows for the three months ended September 30 : 2018 2017 (In thousands) Unrealized appreciation on securities, before tax $ (51 ) $ 53 Tax benefit (expense) 13 (1) (20 ) Unrealized appreciation on securities, net of tax $ (38 ) $ 33 _______________________ (1) Due to the implementation of ASU 2018-02, the tax rate changed from 37.75% to 24.5%. Changes in accumulated other comprehensive income (loss) by component, net of tax, for the three months ended September 30 are as follows: Net Gains on Equity Securities 2018 2017 (In thousands) Balance at June 30: $ (65 ) $ 20 Unrealized appreciation (loss) before reclassifications (38 ) (1) 33 Amounts reclassified from accumulated other comprehensive income — — Net current-period other comprehensive income (loss) (38 ) 33 Balance at September 30: $ (103 ) $ 53 _______________________ (1) Due to the implementation of ASU 2018-02, the tax rate changed from 37.75% to 24.5%. Components of accumulated other comprehensive income (loss) were as follows for the nine months ended September 30 : 2018 2017 (In thousands) Unrealized appreciation (loss) on securities, before tax $ (239 ) $ 85 Tax benefit (expense) 60 (1) (32 ) Unrealized appreciation (loss) on securities, net of tax $ (179 ) $ 53 _______________________ (1) Due to the implementation of ASU 2018-02, the tax rate changed from 37.75% to 24.5%. Changes in accumulated other comprehensive income by component, net of tax, for the nine months ended September 30 are as follows: Net Gains on Equity Securities 2018 2017 (In thousands) Balance at December 31, 2017 $ 63 $ — Adjustment due to ASU 2018-02 13 (1) — Balance at January 1: 76 — Unrealized appreciation (loss) before reclassifications (179 ) (1) 53 Amounts reclassified from accumulated other comprehensive income — — Net current-period other comprehensive income (loss) (179 ) 53 Balance at September 30: $ (103 ) $ 53 _______________________ (1) Due to the implementation of ASU 2018-02, the tax rate changed from 37.75% to 24.5%.

Industry Segment Information

Industry Segment Information	9 Months Ended
	Sep. 30, 2018
Segment Reporting [Abstract]
Industry Segment Information	INDUSTRY SEGMENT INFORMATION We have three main business segments offering different products and services within the energy industry: • Oil and natural gas, • Contract drilling, and • Mid-stream Our oil and natural gas segment is engaged in the acquisition, development, and production of oil, NGLs, and natural gas properties. The contract drilling segment is engaged in the land contract drilling of oil and natural gas wells and the mid-stream segment is engaged in the buying, selling, gathering, processing, and treating of natural gas and NGLs. We evaluate each segment’s performance based on its operating income, which is defined as operating revenues less operating expenses and depreciation, depletion, amortization, and impairment. We have no oil and natural gas production outside the United States. The following tables provide certain information about the operations of each of our segments: Three Months Ended September 30, 2018 Oil and Natural Gas Contract Drilling Mid-stream Other Eliminations Total Consolidated (In thousands) Revenues: (1) Oil and natural gas $ 111,623 $ — $ — $ — $ — $ 111,623 Contract drilling — 58,012 — — (7,400 ) 50,612 Gas gathering and processing — — 82,882 — (25,059 ) 57,823 Total revenues 111,623 58,012 82,882 — (32,459 ) 220,058 Expenses: Operating costs: Oil and natural gas 33,400 — — — (1,261 ) 32,139 Contract drilling — 38,246 — — (6,214 ) 32,032 Gas gathering and processing — — 66,932 3,808 (27,606 ) 43,134 Total operating costs 33,400 38,246 66,932 3,808 (35,081 ) 107,305 Depreciation, depletion, and amortization 35,460 14,889 11,265 1,923 — 63,537 Total expenses 68,860 53,135 78,197 5,731 (35,081 ) 170,842 General and administrative — — — 9,278 — 9,278 Gain on disposition of assets (7 ) (230 ) (16 ) — — (253 ) Income (loss) from operations 42,770 5,107 4,701 (15,009 ) 2,622 40,191 Loss on derivatives — — — (4,385 ) — (4,385 ) Interest, net — — (381 ) (7,564 ) — (7,945 ) Other — — — 3,814 (3,808 ) 6 Income (loss) before income taxes $ 42,770 $ 5,107 $ 4,320 $ (23,144 ) $ (1,186 ) $ 27,867 _______________________ (1) The revenues for oil and natural gas occur at a point in time. The revenues for contract drilling and gas gathering and processing occur over time. Three Months Ended September 30, 2017 Oil and Natural Gas Contract Drilling Mid-stream Other Eliminations Total Consolidated (In thousands) Revenues: Oil and natural gas $ 85,470 $ — $ — $ — $ — $ 85,470 Contract drilling — 55,588 — — (3,969 ) 51,619 Gas gathering and processing — — 69,057 — (17,658 ) 51,399 Total revenues 85,470 55,588 69,057 — (21,627 ) 188,488 Expenses: Operating costs: Oil and natural gas 35,082 — — — (1,171 ) 33,911 Contract drilling — 38,115 — — (3,368 ) 34,747 Gas gathering and processing — — 54,602 — (16,486 ) 38,116 Total operating costs 35,082 38,115 54,602 — (21,025 ) 106,774 Depreciation, depletion, and amortization 26,460 15,280 10,880 1,913 — 54,533 Total expenses 61,542 53,395 65,482 1,913 (21,025 ) 161,307 General and administrative expense — — — 9,235 — 9,235 (Gain) loss on disposition of assets 1 (68 ) (14 ) — — (81 ) Income (loss) from operations 23,927 2,261 3,589 (11,148 ) (602 ) 18,027 Loss on derivatives — — — (2,614 ) — (2,614 ) Interest, net — — — (9,944 ) — (9,944 ) Other — — — 5 — 5 Income (loss) before income taxes $ 23,927 $ 2,261 $ 3,589 $ (23,701 ) $ (602 ) $ 5,474 Nine Months Ended September 30, 2018 Oil and Natural Gas Contract Drilling Mid-stream Other Eliminations Total Consolidated (In thousands) Revenues: (1) Oil and natural gas $ 317,040 $ — $ — $ — $ — $ 317,040 Contract drilling — 161,489 — — (17,962 ) 143,527 Gas gathering and processing — — 232,938 — (65,012 ) 167,926 Total revenues 317,040 161,489 232,938 — (82,974 ) 628,493 Expenses: Operating costs: Oil and natural gas 104,234 — — — (3,715 ) 100,519 Contract drilling — 111,121 — — (15,528 ) 95,593 Gas gathering and processing — — 185,738 7,384 (68,681 ) 124,441 Total operating costs 104,234 111,121 185,738 7,384 (87,924 ) 320,553 Depreciation, depletion, and amortization 97,797 41,927 33,493 5,759 — 178,976 Total expenses 202,031 153,048 219,231 13,143 (87,924 ) 499,529 General and administrative expense — — — 28,752 — 28,752 Gain on disposition of assets (136 ) (314 ) (95 ) (30 ) — (575 ) Income (loss) from operations 115,145 8,755 13,802 (41,865 ) 4,950 100,787 Loss on derivatives — — — (25,608 ) — (25,608 ) Interest, net — — (834 ) (24,844 ) — (25,678 ) Other — — — 7,401 (7,384 ) 17 Income (loss) before income taxes $ 115,145 $ 8,755 $ 12,968 $ (84,916 ) $ (2,434 ) $ 49,518 _______________________ (1) The revenues for oil and natural gas occur at a point in time. The revenues for contract drilling and gas gathering and processing occur over time. Nine Months Ended September 30, 2017 Oil and Natural Gas Contract Drilling Mid-stream Other Eliminations Total Consolidated (In thousands) Revenues: Oil and natural gas $ 256,241 $ — $ — $ — $ — $ 256,241 Contract drilling — 137,617 — — (9,558 ) 128,059 Gas gathering and processing — — 198,632 — (48,139 ) 150,493 Total revenues 256,241 137,617 198,632 — (57,697 ) 534,793 Expenses: Operating costs: Oil and natural gas 99,349 — — — (3,476 ) 95,873 Contract drilling — 99,794 — — (8,581 ) 91,213 Gas gathering and processing — — 156,525 — (44,663 ) 111,862 Total operating costs 99,349 99,794 156,525 — (56,720 ) 298,948 Depreciation, depletion, and amortization 71,544 41,896 32,547 5,558 — 151,545 Total expenses 170,893 141,690 189,072 5,558 (56,720 ) 450,493 General and administrative expense — — — 26,902 — 26,902 Gain on disposition of assets (176 ) (106 ) (58 ) (813 ) — (1,153 ) Income (loss) from operations 85,524 (3,967 ) 9,618 (31,647 ) (977 ) 58,551 Gain on derivatives — — — 21,019 — 21,019 Interest, net — — — (28,807 ) — (28,807 ) Other — — — 14 — 14 Income (loss) before income taxes $ 85,524 $ (3,967 ) $ 9,618 $ (39,421 ) $ (977 ) $ 50,777

Supplemental Condensed Consolid

Supplemental Condensed Consolidated Financial Information	9 Months Ended
	Sep. 30, 2018
Supplemental Condensed Consolidated Financial Information [Abstract]
Condensed Consolidated Financial Statements	SUPPLEMENTAL CONDENSED CONSOLIDATING FINANCIAL INFORMATION We have no significant assets or operations other than our investments in our subsidiaries. Our wholly owned subsidiaries are the guarantors of our Notes. On April 3, 2018 , we sold 50% of the ownership interest in our mid-stream segment, Superior and that company and its subsidiaries are no longer guarantors of the Notes. Instead of providing separate financial statements for each subsidiary issuer and guarantor, we have included the accompanying unaudited condensed consolidating financial statements based on Rule 3-10 of the SEC's Regulation S-X. For purposes of the following footnote: • we are referred to as "Parent", • the direct subsidiaries are 100% owned by the Parent and the guarantee is full and unconditional and joint and several and referred to as "Combined Guarantor Subsidiaries", and • Superior and its subsidiaries and the Operator are referred to as "Non-Guarantor Subsidiaries." The following unaudited supplemental condensed consolidating financial information reflects the Parent's separate accounts, the combined accounts of the Combined Guarantor Subsidiaries', the combined accounts of the Non-Guarantor Subsidiaries', the combined consolidating adjustments and eliminations, and the Parent's consolidated amounts for the periods indicated. Condensed Consolidating Balance Sheets (Unaudited) September 30, 2018 Parent Combined Guarantor Subsidiaries Combined Non-Guarantor Subsidiaries Consolidating Adjustments Total Consolidated (In thousands) ASSETS Current assets: Cash and cash equivalents $ 82,267 $ 251 $ 9,039 $ — $ 91,557 Accounts receivable, net of allowance for doubtful accounts of $2,450 (Guarantor of $1,245 and Non-Guarantor of $1,205) 1,374 92,078 28,671 — 122,123 Materials and supplies — 505 — — 505 Current derivative asset — — — — — Prepaid expenses and other 3,125 3,538 2,756 — 9,419 Total current assets 86,766 96,372 40,466 — 223,604 Property and equipment: Oil and natural gas properties on the full cost method: Proved properties — 5,901,661 — — 5,901,661 Unproved properties not being amortized — 332,886 — — 332,886 Drilling equipment — 1,632,540 — — 1,632,540 Gas gathering and processing equipment — — 751,715 — 751,715 Saltwater disposal systems — 67,074 — — 67,074 Corporate land and building — 59,081 — — 59,081 Transportation equipment 9,273 16,766 3,064 — 29,103 Other 28,506 28,244 — — 56,750 37,779 8,038,252 754,779 — 8,830,810 Less accumulated depreciation, depletion, amortization, and impairment 25,922 5,945,762 353,476 — 6,325,160 Net property and equipment 11,857 2,092,490 401,303 — 2,505,650 Intercompany receivable 907,907 — — (907,907 ) — Goodwill — 62,808 — — 62,808 Investments 1,248,309 1,500 — (1,248,309 ) 1,500 Other assets 5,605 6,186 15,412 — 27,203 Total assets $ 2,260,444 $ 2,259,356 $ 457,181 $ (2,156,216 ) $ 2,820,765 September 30, 2018 Parent Combined Guarantor Subsidiaries Combined Non-Guarantor Subsidiaries Consolidating Adjustments Total Consolidated (In thousands) LIABILITIES AND SHAREHOLDERS’ EQUITY Current liabilities: Accounts payable $ 28,116 $ 90,543 $ 24,893 $ — $ 143,552 Accrued liabilities 36,444 26,583 4,716 — 67,743 Income taxes payable 1,051 — — — 1,051 Current derivative liability 13,067 — — — 13,067 Current portion of other long-term liabilities 966 6,348 6,836 — 14,150 Total current liabilities 79,644 123,474 36,445 — 239,563 Intercompany debt — 906,296 1,086 (907,382 ) — Bonds payable less debt issuance costs 643,921 — — — 643,921 Non-current derivative liabilities 1,542 — — — 1,542 Other long-term liabilities 12,790 72,494 16,126 — 101,410 Deferred income taxes 54,707 110,257 — — 164,964 Shareholders’ equity: Preferred stock, $1.00 par value, 5,000,000 shares authorized, none issued — — — — — Common stock, $.20 par value, 175,000,000 shares authorized, 54,063,705 shares issued 10,414 — — — 10,414 Capital in excess of par value 626,746 45,921 197,042 (242,963 ) 626,746 Contributions from Unit — — 525 (525 ) — Accumulated other comprehensive loss — (103 ) — — (103 ) Retained earnings 830,680 1,001,017 4,329 (1,005,346 ) 830,680 Total shareholders’ equity attributable to Unit Corporation 1,467,840 1,046,835 201,896 (1,248,834 ) 1,467,737 Non-controlling interests in consolidated subsidiaries — — 201,628 — 201,628 Total shareholders' equity 1,467,840 1,046,835 403,524 (1,248,834 ) 1,669,365 Total liabilities and shareholders’ equity $ 2,260,444 $ 2,259,356 $ 457,181 $ (2,156,216 ) $ 2,820,765 December 31, 2017 Parent Combined Guarantor Subsidiaries Combined Non-Guarantor Subsidiaries Consolidating Adjustments Total Consolidated (In thousands) ASSETS Current assets: Cash and cash equivalents $ 510 $ 191 $ — $ — $ 701 Accounts receivable, net of allowance for doubtful accounts of $2,450 (Guarantor of $1,245 and Non-Guarantor of $1,205) 154 83,442 27,916 — 111,512 Materials and supplies — 505 — — 505 Current derivative asset 721 — — — 721 Prepaid expenses and other 2,986 2,370 877 — 6,233 Total current assets 4,371 86,508 28,793 — 119,672 Property and equipment: Oil and natural gas properties on the full cost method: Proved properties — 5,712,813 — — 5,712,813 Unproved properties not being amortized — 296,764 — — 296,764 Drilling equipment — 1,593,611 — — 1,593,611 Gas gathering and processing equipment — — 726,236 — 726,236 Saltwater disposal systems — 62,618 — — 62,618 Corporate land and building — 59,080 — — 59,080 Transportation equipment 9,270 17,423 2,938 — 29,631 Other 28,039 25,400 — — 53,439 37,309 7,767,709 729,174 — 8,534,192 Less accumulated depreciation, depletion, amortization, and impairment 21,268 5,807,757 322,425 — 6,151,450 Net property and equipment 16,041 1,959,952 406,749 — 2,382,742 Intercompany receivable 1,155,725 — — (1,155,725 ) — Goodwill — 62,808 — — 62,808 Investments 1,044,709 1,500 — (1,044,709 ) 1,500 Other assets 5,373 6,328 3,029 — 14,730 Total assets $ 2,226,219 $ 2,117,096 $ 438,571 $ (2,200,434 ) $ 2,581,452 December 31, 2017 Parent Combined Guarantor Subsidiaries Combined Non-Guarantor Subsidiaries Consolidating Adjustments Total Consolidated (In thousands) LIABILITIES AND SHAREHOLDERS’ EQUITY Current liabilities: Accounts payable $ 13,124 $ 81,334 $ 18,190 $ — $ 112,648 Accrued liabilities 26,165 19,134 3,224 — 48,523 Current derivative liability 7,763 — — — 7,763 Current portion of other long-term liabilities 657 8,501 3,844 — 13,002 Total current liabilities 47,709 108,969 25,258 — 181,936 Intercompany debt — 870,582 285,143 (1,155,725 ) — Long-term debt 178,000 — — — 178,000 Bonds payable less debt issuance costs 642,276 — — — 642,276 Other long-term liabilities 11,257 77,566 11,380 — 100,203 Deferred income taxes 1,480 85,443 46,554 — 133,477 Shareholders’ equity: Preferred stock, $1.00 par value, 5,000,000 shares authorized, none issued — — — — — Common stock, $.20 par value, 175,000,000 shares authorized, 52,880,134 shares issued 10,280 — — — 10,280 Capital in excess of par value 535,815 45,921 15,549 (61,470 ) 535,815 Accumulated other comprehensive income — 63 — — 63 Retained earnings 799,402 928,552 54,687 (983,239 ) 799,402 Total shareholders’ equity attributable to Unit Corporation 1,345,497 974,536 70,236 (1,044,709 ) 1,345,560 Non-controlling interests in consolidated subsidiaries — — — — — Total shareholders' equity 1,345,497 974,536 70,236 (1,044,709 ) 1,345,560 Total liabilities and shareholders’ equity $ 2,226,219 $ 2,117,096 $ 438,571 $ (2,200,434 ) $ 2,581,452 Condensed Consolidating Statements of Income (Unaudited) Three Months Ended September 30, 2018 Parent Combined Guarantor Subsidiaries Combined Non-Guarantor Subsidiaries Consolidating Adjustments Total Consolidated (In thousands) Revenues $ — $ 169,635 $ 82,882 $ (32,459 ) $ 220,058 Expenses: Operating costs — 71,646 66,932 (31,273 ) 107,305 Depreciation, depletion, and amortization 1,923 50,349 11,265 — 63,537 General and administrative — 9,252 26 — 9,278 Gain on disposition of assets — (237 ) (16 ) — (253 ) Total operating costs 1,923 131,010 78,207 (31,273 ) 179,867 Income from operations (1,923 ) 38,625 4,675 (1,186 ) 40,191 Interest, net (7,564 ) — (381 ) — (7,945 ) Loss on derivatives (4,385 ) — — — (4,385 ) Other, net 6 (1 ) 1 — 6 Income (loss) before income taxes (13,866 ) 38,624 4,295 (1,186 ) 27,867 Income tax expense (benefit) (3,688 ) 9,839 593 — 6,744 Equity in net earnings from investment in subsidiaries, net of taxes 29,077 — — (29,077 ) — Net income 18,899 28,785 3,702 (30,263 ) 21,123 Less: net income attributable to non-controlling interest — — 2,224 — 2,224 Net income attributable to Unit Corporation $ 18,899 $ 28,785 $ 1,478 $ (30,263 ) $ 18,899 Three Months Ended September 30, 2017 Parent Combined Guarantor Subsidiaries Combined Non-Guarantor Subsidiaries Consolidating Adjustments Total Consolidated (In thousands) Revenues $ — $ 141,058 $ 69,057 $ (21,627 ) $ 188,488 Expenses: Operating costs — 73,197 54,603 (21,026 ) 106,774 Depreciation, depletion, and amortization 1,913 41,740 10,880 — 54,533 General and administrative — 7,083 2,152 — 9,235 Gain on disposition of assets — (67 ) (14 ) — (81 ) Total operating costs 1,913 121,953 67,621 (21,026 ) 170,461 Income (loss) from operations (1,913 ) 19,105 1,436 (601 ) 18,027 Interest, net (9,776 ) — (168 ) — (9,944 ) Loss on derivatives (2,614 ) — — — (2,614 ) Other, net 5 — — — 5 Income (loss) before income taxes (14,298 ) 19,105 1,268 (601 ) 5,474 Income tax expense (benefit) (5,626 ) 7,003 392 — 1,769 Equity in net earnings from investment in subsidiaries, net of taxes 12,377 — — (12,377 ) — Net income 3,705 12,102 876 (12,978 ) 3,705 Less: net income attributable to non-controlling interest — — — — — Net income attributable to Unit Corporation $ 3,705 $ 12,102 $ 876 $ (12,978 ) $ 3,705 Nine Months Ended September 30, 2018 Parent Combined Guarantor Subsidiaries Combined Non-Guarantor Subsidiaries Consolidating Adjustments Total Consolidated (In thousands) Revenues $ — $ 478,529 $ 232,938 $ (82,974 ) $ 628,493 Expenses: Operating costs — 215,355 185,738 (80,540 ) 320,553 Depreciation, depletion, and amortization 5,759 139,724 33,493 — 178,976 General and administrative — 26,136 2,616 — 28,752 Gain on disposition of assets (30 ) (450 ) (95 ) — (575 ) Total operating costs 5,729 380,765 221,752 (80,540 ) 527,706 Income (loss) from operations (5,729 ) 97,764 11,186 (2,434 ) 100,787 Interest, net (24,844 ) — (834 ) — (25,678 ) Loss on derivatives (25,608 ) — — — (25,608 ) Other, net 17 — — — 17 Income (loss) before income taxes (56,164 ) 97,764 10,352 (2,434 ) 49,518 Income tax expense (benefit) (14,356 ) 25,299 1,437 — 12,380 Equity in net earnings from investment in subsidiaries, net of tax 74,360 — — (74,360 ) — Net income 32,552 72,465 8,915 (76,794 ) 37,138 Less: net income attributable to non-controlling interest — — 4,586 — 4,586 Net income attributable to Unit Corporation $ 32,552 $ 72,465 $ 4,329 $ (76,794 ) $ 32,552 Nine Months Ended September 30, 2017 Parent Combined Guarantor Subsidiaries Combined Non-Guarantor Subsidiaries Consolidating Adjustments Total Consolidated (In thousands) Revenues $ — $ 393,858 $ 198,632 $ (57,697 ) $ 534,793 Expenses: Operating costs — 199,143 156,525 (56,720 ) 298,948 Depreciation, depletion, and amortization 5,558 113,440 32,547 — 151,545 General and administrative — 20,880 6,022 — 26,902 Gain on disposition of assets (813 ) (282 ) (58 ) — (1,153 ) Total operating costs 4,745 333,181 195,036 (56,720 ) 476,242 Income (loss) from operations (4,745 ) 60,677 3,596 (977 ) 58,551 Interest, net (28,276 ) — (531 ) — (28,807 ) Gain on derivatives 21,019 — — — 21,019 Other, net 14 — — — 14 Income (loss) before income taxes (11,988 ) 60,677 3,065 (977 ) 50,777 Income tax expense (benefit) (4,895 ) 25,357 1,622 — 22,084 Equity in net earnings from investment in subsidiaries, net of tax 35,786 — — (35,786 ) — Net income 28,693 35,320 1,443 (36,763 ) 28,693 Less: net income attributable to non-controlling interest — — — — — Net income attributable to Unit Corporation $ 28,693 $ 35,320 $ 1,443 $ (36,763 ) $ 28,693 Condensed Consolidating Statements of Comprehensive Income (Unaudited) Three Months Ended September 30, 2018 Parent Combined Guarantor Subsidiaries Combined Non-Guarantor Subsidiaries Consolidating Adjustments Total Consolidated (In thousands) Net income $ 18,899 $ 28,785 $ 3,702 $ (30,263 ) $ 21,123 Other comprehensive income, net of taxes: Unrealized loss on securities, net of tax ($13) — (38 ) — — (38 ) Comprehensive income 18,899 28,747 3,702 (30,263 ) 21,085 Less: Comprehensive income attributable to non-controlling interests — — 2,224 — 2,224 Comprehensive income attributable to Unit Corporation $ 18,899 $ 28,747 $ 1,478 $ (30,263 ) $ 18,861 Three Months Ended September 30, 2017 Parent Combined Guarantor Subsidiaries Combined Non-Guarantor Subsidiaries Consolidating Adjustments Total Consolidated (In thousands) Net income $ 3,705 $ 12,102 $ 876 $ (12,978 ) $ 3,705 Other comprehensive income, net of taxes: Unrealized gain on securities, net of tax of $20 — 33 — — 33 Comprehensive income 3,705 12,135 876 (12,978 ) 3,738 Less: Comprehensive income attributable to non-controlling interests — — — — — Comprehensive income attributable to Unit Corporation $ 3,705 $ 12,135 $ 876 $ (12,978 ) $ 3,738 Nine Months Ended September 30, 2018 Parent Combined Guarantor Subsidiaries Combined Non-Guarantor Subsidiaries Consolidating Adjustments Total Consolidated (In thousands) Net income $ 32,552 $ 72,465 $ 8,915 $ (76,794 ) $ 37,138 Other comprehensive income, net of taxes: Unrealized loss on securities, net of tax of ($60) — (179 ) — — (179 ) Comprehensive income 32,552 72,286 8,915 (76,794 ) 36,959 Less: Comprehensive income attributable to non-controlling interests — — 4,586 — 4,586 Comprehensive income attributable to Unit Corporation $ 32,552 $ 72,286 $ 4,329 $ (76,794 ) $ 32,373 Nine Months Ended September 30, 2017 Parent Combined Guarantor Subsidiaries Combined Non-Guarantor Subsidiaries Consolidating Adjustments Total Consolidated (In thousands) Net income $ 28,693 $ 35,320 $ 1,443 $ (36,763 ) $ 28,693 Other comprehensive income, net of taxes: Unrealized gain on securities, net of tax of $32 — 53 — — 53 Comprehensive income 28,693 35,373 1,443 (36,763 ) 28,746 Less: Comprehensive income attributable to non-controlling interests — — — — — Comprehensive income attributable to Unit Corporation $ 28,693 $ 35,373 $ 1,443 $ (36,763 ) $ 28,746 Condensed Consolidating Statements of Cash Flows (Unaudited) Nine Months Ended September 30, 2018 Parent Combined Guarantor Subsidiaries Combined Non-Guarantor Subsidiaries Consolidating Adjustments Total Consolidated (In thousands) OPERATING ACTIVITIES: Net cash provided by (used in) operating activities (103,436 ) 215,350 (3,984 ) 128,605 236,535 INVESTING ACTIVITIES: Capital expenditures 22 (275,434 ) (28,642 ) — (304,054 ) Producing properties and other acquisitions — (769 ) — — (769 ) Proceeds from disposition of assets 30 25,199 87 — 25,316 Net cash provided by (used in) investing activities 52 (251,004 ) (28,555 ) — (279,507 ) FINANCING ACTIVITIES: Borrowings under credit agreement 69,200 — 2,000 — 71,200 Payments under credit agreement (247,200 ) — (2,000 ) — (249,200 ) Intercompany borrowings (advances), net 248,343 35,714 (155,977 ) (128,080 ) — Payments on capitalized leases — — (2,869 ) — (2,869 ) Proceeds from investments of non-controlling interest 102,958 — 197,042 — 300,000 Contributions from Unit — — 525 (525 ) — Transaction costs associated with sale of non-controlling interest (2,303 ) — — — (2,303 ) Book overdrafts 14,143 — 2,857 — 17,000 Net cash provided by financing activities 185,141 35,714 41,578 (128,605 ) 133,828 Net increase in cash and cash equivalents 81,757 60 9,039 — 90,856 Cash and cash equivalents, beginning of period 510 191 — — 701 Cash and cash equivalents, end of period $ 82,267 $ 251 $ 9,039 $ — $ 91,557 Nine Months Ended September 30, 2017 Parent Combined Guarantor Subsidiaries Combined Non-Guarantor Subsidiaries Consolidating Adjustments Total Consolidated (In thousands) OPERATING ACTIVITIES: Net cash provided by operating activities 822 149,963 34,007 — 184,792 INVESTING ACTIVITIES: Capital expenditures (3,595 ) (152,055 ) (11,742 ) — (167,392 ) Producing properties and other acquisitions — (55,429 ) — — (55,429 ) Proceeds from disposition of assets 955 19,124 58 — 20,137 Other — (1,500 ) — — (1,500 ) Net cash used in investing activities (2,640 ) (189,860 ) (11,684 ) — (204,184 ) FINANCING ACTIVITIES: Borrowings under credit agreement 251,401 — — — 251,401 Payments under credit agreement (250,100 ) — — — (250,100 ) Intercompany borrowings (advances), net (20,483 ) 39,839 (19,356 ) — — Payments on capitalized leases — — (2,967 ) — (2,967 ) Proceeds from common stock issued, net of issue costs 18,623 — — — 18,623 Book overdrafts 2,364 — — — 2,364 Net cash provided by (used in) financing activities 1,805 39,839 (22,323 ) — 19,321 Net decrease in cash and cash equivalents (13 ) (58 ) — — (71 ) Cash and cash equivalents, beginning of period 517 376 — — 893 Cash and cash equivalents, end of period $ 504 $ 318 $ — $ — $ 822

Subsequent Event

Subsequent Event	9 Months Ended
	Sep. 30, 2018
Subsequent Events [Abstract]
Subsequent Events	SUBSEQUENT EVENT On October 18, 2018, we signed the fifth amendment to the Unit credit agreement originally scheduled to mature on April 10, 2020. The Fifth Amendment, among other things, (i) extends the term of the Unit credit agreement to October 18, 2023, subject to certain conditions; (ii) reduces the pricing for borrowing and non-use fees; and (iii) eliminates the requirement that the company maintain a senior indebtedness to consolidated EBITDA ratio. The total commitment of credit and the borrowing base both remain unchanged at $425.0 million. A copy of the Fifth Amendment is filed as Exhibit 10.1 to this report.

Revenues from Contracts with Cu

Revenues from Contracts with Customers (Tables)	9 Months Ended
	Sep. 30, 2018
Revenue From Contracts with Customers [Abstract]
Revenue Impact of the Adoption of ASC606	These tables summarize the impact of the adoption of ASC 606 on revenue and operating costs for the three and nine months ended September 30, 2018 , respectively: Three Months Ended September 30, 2018 As Reported Adjustments due to ASC 606 Amounts without the Adoption of ASC 606 (In thousands) Oil and natural gas revenues $ 111,623 $ (5,200 ) $ 116,823 Oil and natural gas operating costs 32,139 (5,200 ) 37,339 Gross profit $ 79,484 $ — $ 79,484 Nine Months Ended September 30, 2018 As Reported Adjustments due to ASC 606 Amounts without the Adoption of ASC 606 (In thousands) Oil and natural gas revenues $ 317,040 $ (12,102 ) $ 329,142 Oil and natural gas operating costs 100,519 (12,102 ) 112,621 Gross profit $ 216,521 $ — $ 216,521 For the three months ended September 30, 2018 : As Reported Adjustments due to ASC 606 Amounts without the Adoption of ASC 606 (In thousands) Gas gathering and processing revenues $ 57,823 $ 1,300 $ 56,523 Deferred income tax expense 6,744 318 6,426 Net income 21,123 982 20,141 This adjustment related to the timing of revenue recognized on certain demand fees and had the following impact to the Unaudited Condensed Consolidated Income Statement for the nine months ended September 30, 2018 : As Reported Adjustments due to ASC 606 Amounts without the Adoption of ASC 606 (In thousands) Gas gathering and processing revenues $ 167,926 $ 3,671 $ 164,255 Deferred income tax expense 12,380 899 11,481 Net income 37,138 2,772 34,366
Balance Sheet Impact of the Adoption of ASC606	This adjustment—related to the timing of revenue recognized on certain demand fees—impacted our Unaudited Condensed Consolidated Balance Sheet (for the periods indicated) as follows: Balance at December 31, 2017 Adjustments due to ASC 606 Balance at January 1, 2018 (In thousands) Assets: Other assets $ 16,230 $ 10,798 $ 27,028 Liabilities and shareholders' equity: Current portion of other long-term liabilities 13,002 2,748 15,750 Other long-term liabilities 100,203 9,737 109,940 Deferred income taxes 133,477 (413 ) 133,064 Retained earnings 799,402 (1,274 ) 798,128 At September 30, 2018 : As Reported Adjustments due to ASC 606 Amounts without the Adoption of ASC 606 (In thousands) Assets: Prepaid expenses and other $ 9,419 $ 206 $ 9,213 Other assets 28,703 12,383 16,320 Liabilities and shareholders' equity: Current portion of other long-term liabilities 14,150 2,874 11,276 Other long-term liabilities 101,410 7,731 93,679 Deferred income taxes 164,964 486 164,478 Retained earnings 830,680 1,498 829,182
Revenue, Remaining Performance Obligation	Included below is the additional fixed revenue we will earn over the remaining term of the contracts and excludes all variable consideration to be earned with the associated contract. Contract Remaining Term of Contract October - December 2018 2019 2020 2021 2022 Total Remaining Impact to Revenue (In thousands) Demand fee contracts 4-5 years $ 1,299 $ 2,632 $ (3,781 ) $ (3,507 ) $ 1,374 $ (1,983 )
Contract with Customer, Asset and Liability	September 30, January 1, Change (In thousands) Contract assets $ 12,589 $ 10,798 $ 1,791 Contract liabilities 10,605 12,485 (1,880 ) Contract assets (liabilities), net $ 1,984 $ (1,687 ) $ 3,671

Earnings Per Share (Tables)

Earnings Per Share (Tables)	9 Months Ended
	Sep. 30, 2018
Earnings Per Share [Abstract]
Schedule of Earnings Per Share	Information related to the calculation of earnings per share attributable to Unit Corporation follows: Earnings (Numerator) Weighted Shares (Denominator) Per-Share Amount (In thousands except per share amounts) For the three months ended September 30, 2018 Basic earnings attributable to Unit Corporation per common share $ 18,899 52,068 $ 0.36 Effect of dilutive stock options and restricted stock — 1,072 — Diluted earnings attributable to Unit Corporation per common share $ 18,899 53,140 $ 0.36 For the three months ended September 30, 2017 Basic earnings attributable to Unit Corporation per common share $ 3,705 51,386 $ 0.07 Effect of dilutive stock options, restricted stock, and stock appreciation rights (SARs) — 586 — Diluted earnings attributable to Unit Corporation per common share $ 3,705 51,972 $ 0.07 Earnings (Loss) Weighted Shares (Denominator) Per-Share Amount (In thousands except per share amounts) For the nine months ended September 30, 2018 Basic earnings attributable to Unit Corporation per common share $ 32,552 51,951 $ 0.63 Effect of dilutive stock options and restricted stock — 808 (0.01 ) Diluted earnings attributable to Unit Corporation per common share $ 32,552 52,759 $ 0.62 For the nine months ended September 30, 2017 Basic earnings attributable to Unit Corporation per common share $ 28,693 51,019 $ 0.56 Effect of dilutive stock options, restricted stock, and SARs — 550 — Diluted earnings attributable to Unit Corporation per common share $ 28,693 51,569 $ 0.56
Schedule of Antidilutive Securities Excluded From Computation of Earnings Per Share	The following table shows the number of stock options and SARs (and their average exercise price) excluded because their option exercise prices were greater than the average market price of our common stock: Three Months Ended September 30, 2018 2017 Stock options and SARs 66,500 178,755 Average exercise price $ 44.42 $ 47.75 The following table shows the number of stock options and SARs (and their average exercise price) excluded because their option exercise prices were greater than the average market price of our common stock: Nine Months Ended September 30, 2018 2017 Stock options and SARs 66,500 178,755 Average exercise price $ 44.42 $ 47.75

Accrued Liabilities (Tables)

Accrued Liabilities (Tables)	9 Months Ended
	Sep. 30, 2018
Accrued Liabilities [Abstract]
Accrued Liabilities	Accrued liabilities consisted of: September 30, December 31, (In thousands) Employee costs $ 17,880 $ 19,521 Interest payable 17,446 6,745 Lease operating expenses 11,474 11,819 Taxes 10,317 3,404 Derivative settlements 3,383 — Third-party credits 2,099 2,240 Other 5,144 4,794 Total accrued liabilities $ 67,743 $ 48,523

Long-Term Debt And Other Long_2

Long-Term Debt And Other Long-Term Liabilities (Tables)	9 Months Ended
	Sep. 30, 2018
Debt Disclosure [Abstract]
Long-Term Debt	Our long-term debt as of the dates indicated consisted of the following: September 30, December 31, (In thousands) Unit credit agreement with an average interest rate of 3.4% at December 31, 2017 $ — $ 178,000 Superior credit agreement — — 6.625% senior subordinated notes due 2021 650,000 650,000 Total principal amount 650,000 828,000 Less: unamortized discount (1,780 ) (2,234 ) Less: debt issuance costs, net (4,299 ) (5,490 ) Total long-term debt $ 643,921 $ 820,276
Other Long-Term Liabilities	Other long-term liabilities consisted of the following: September 30, December 31, (In thousands) Asset retirement obligation (ARO) liability $ 62,727 $ 69,444 Workers’ compensation 12,832 13,340 Capital lease obligations 12,355 15,224 Contract liability 10,605 — Separation benefit plans 8,135 6,524 Deferred compensation plan 5,623 5,390 Gas balancing liability 3,283 3,283 115,560 113,205 Less current portion 14,150 13,002 Total other long-term liabilities $ 101,410 $ 100,203
Capital leases	Future payments required under the capital leases at September 30, 2018 are: Amount Beginning October 1, (In thousands) 2018 $ 6,195 2019 6,195 2020 5,322 Total future payments 17,712 Less payments related to: Maintenance 4,601 Interest 756 Present value of future minimum payments $ 12,355

Asset Retirement Obligations (T

Asset Retirement Obligations (Tables)	9 Months Ended
	Sep. 30, 2018
Asset Retirement Obligation Disclosure [Abstract]
Schedule of Asset Retirement Obligations	The following table shows certain information about our AROs for the periods indicated: Nine Months Ended September 30, 2018 2017 (In thousands) ARO liability, January 1: $ 69,444 $ 70,170 Accretion of discount 1,829 2,112 Liability incurred 244 1,123 Liability settled (3,907 ) (1,350 ) Liability sold (105 ) (1,563 ) Revision of estimates (1) (4,778 ) 4,993 ARO liability, September 30: 62,727 75,485 Less current portion 1,451 2,947 Total long-term ARO $ 61,276 $ 72,538 _______________________ (1) Plugging liability estimates were revised in both 2018 and 2017 for updates in the cost of services used to plug wells over the preceding year. We had various upward and downward adjustments.

Stock-Based Compensation (Table

Stock-Based Compensation (Tables)	9 Months Ended
	Sep. 30, 2018
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]
Schedule of Restricted Stock Awards and Stock Options	For restricted stock awards and stock options, we had: Three Months Ended Nine Months Ended September 30, September 30, 2018 2017 2018 2017 (In millions) Recognized stock compensation expense $ 4.1 $ 3.2 $ 13.6 $ 9.0 Capitalized stock compensation cost for our oil and natural gas properties 0.6 0.5 1.6 1.3 Tax benefit on stock-based compensation 1.0 1.2 3.3 3.4
Schedule of Fair Value of the Restricted Stock Awards Granted During the Periods	This table shows the fair value of restricted stock awards granted to employees and non-employee directors during the periods indicated: Nine Months Ended Nine Months Ended September 30, 2018 September 30, 2017 Time Vested Performance Vested Time Vested Performance Vested Shares granted: Employees 844,498 362,070 475,799 173,373 Non-employee directors 44,312 — 49,104 — 888,810 362,070 524,903 173,373 Estimated fair value (in millions): (1) Employees $ 16.2 $ 7.3 $ 11.8 $ 4.5 Non-employee directors 0.9 — 0.9 — $ 17.1 $ 7.3 $ 12.7 $ 4.5 Percentage of shares granted expected to be distributed: Employees 95 % 74 % 95 % 91 % Non-employee directors 100 % N/A 100 % N/A _______________________ (1) The performance shares represent 100% of the grant date fair value. (We recognize the grant date fair value minus estimated forfeitures.)

Derivatives (Tables)

Derivatives (Tables)	9 Months Ended
	Sep. 30, 2018
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Derivatives outstanding	At September 30, 2018 , these derivatives were outstanding: Term Commodity Contracted Volume Weighted Average Fixed Price Contracted Market Oct'18 Natural gas – swap 30,000 MMBtu/day $3.005 IF – NYMEX (HH) Nov’18 – Dec'18 Natural gas – swap 20,000 MMBtu/day $3.013 IF – NYMEX (HH) Jan'19 – Dec'19 Natural gas – swap 10,000 MMBtu/day $2.810 IF – NYMEX (HH) Oct'18 Natural gas – basis swap 10,000 MMBtu/day $(0.190) NGPL TEXOK Oct'18 – Dec'18 Natural gas – basis swap 10,000 MMBtu/day $(0.678) PEPL Oct'18 – Dec'18 Natural gas – basis swap 10,000 MMBtu/day $(0.568) NGPL MIDCON Nov’18 – Dec'18 Natural gas – basis swap 10,000 MMBtu/day $(0.208) IF – NYMEX (HH) Jan'19 – Dec'19 Natural gas – basis swap 20,000 MMBtu/day $(0.659) PEPL Jan'19 – Dec'19 Natural gas – basis swap 10,000 MMBtu/day $(0.625) NGL MIDCON Jan'19 – Dec'19 Natural gas – basis swap 30,000 MMBtu/day $(0.265) NGPL TEXOK Jan'20 – Dec'20 Natural gas – basis swap 30,000 MMBtu/day $(0.275) NGPL TEXOK Oct'18 – Dec'18 Natural gas – three-way collar 20,000 MMBtu/day $3.00 - $2.50 - $3.51 IF – NYMEX (HH) Oct'18 – Dec'18 Crude oil – swap 4,000 Bbl/day $53.52 WTI – NYMEX Oct'18 – Dec'18 Crude oil – price differential risk 500 Bbl/day $7.00 LLS/WTI Oct'18 – Dec'18 Crude oil – three-way collar 2,000 Bbl/day $47.50 - $37.50 - $56.08 WTI – NYMEX Jan'19 – Dec'19 Crude oil – three-way collar 4,000 Bbl/day $61.25 - $51.25 - $72.93 WTI – NYMEX
Subsequent schedule of derivatives outstanding	After September 30, 2018 , the following derivatives were entered into: Term Commodity Contracted Volume Weighted Average Fixed Price Contracted Market Jan'19 – Dec'19 Natural gas – swap 10,000 MMBtu/day $2.850 IF – NYMEX (HH) Jan'19 – Dec'19 Natural gas – collar 20,000 MMBtu/day $2.63 - $3.03 IF – NYMEX (HH) Jan'19 – Mar'19 Natural gas – three-way collar 10,000 MMBtu/day $3.00 - $2.75 - $4.35 IF – NYMEX (HH)
Fair Value of Derivative Instruments and Locations in Balance Sheets	The following tables present the fair values and locations of the derivative transactions recorded in our Unaudited Condensed Consolidated Balance Sheets: Derivative Assets Fair Value Balance Sheet Location September 30, December 31, (In thousands) Commodity derivatives: Current Current derivative asset $ — $ 721 Long-term Non-current derivative asset — — Total derivative assets $ — $ 721 Derivative Liabilities Fair Value Balance Sheet Location September 30, December 31, (In thousands) Commodity derivatives: Current Current derivative liability $ 13,067 $ 7,763 Long-term Non-current derivative liability 1,542 — Total derivative liabilities $ 14,609 $ 7,763
Effect of Derivative Instruments Recognized in Income Statements, Derivative Instruments	Following is the effect of derivative instruments on the Unaudited Condensed Consolidated Income Statements for the three months ended September 30 : Derivatives Instruments Location of Gain (Loss) Recognized in Income on Derivative Amount of Gain (Loss) Recognized in Income on Derivative 2018 2017 (In thousands) Commodity derivatives Loss on derivatives (1) $ (4,385 ) $ (2,614 ) Total $ (4,385 ) $ (2,614 ) _______________________ (1) Amounts settled during the 2018 and 2017 periods include net payments of $9.1 million and net proceeds of $0.8 million , respectively. Following is the effect of derivative instruments on the Unaudited Condensed Consolidated Income Statements for the nine months ended September 30 : Derivatives Instruments Location of Gain (Loss) Recognized in Income on Derivative Amount of Gain (Loss) Recognized in Income on Derivative 2018 2017 (In thousands) Commodity derivatives Gain (loss) on derivatives (1) $ (25,608 ) $ 21,019 Total $ (25,608 ) $ 21,019 _______________________ (1) Amounts settled during the 2018 and 2017 periods include net payments of $18.0 million and $0.7 million , respectively.

Fair Value Measurements (Tables

Fair Value Measurements (Tables)	9 Months Ended
	Sep. 30, 2018
Fair Value Disclosures [Abstract]
Fair Value of Available-for-sale Securities	The following is a summary of available-for-sale securities: Cost Gross Unrealized Gains Gross Unrealized Losses Estimated Fair Value (In thousands) Equity Securities: September 30, 2018 $ 830 $ — $ 137 $ 693 December 31, 2017 $ 830 $ 102 $ — $ 932
Recurring Fair Value Measurements	The following tables set forth our recurring fair value measurements: September 30, 2018 Level 1 Level 2 Level 3 Effect of Netting Net Amounts Presented (In thousands) Financial assets (liabilities): Commodity derivatives: Assets $ — $ 1,282 $ 88 $ (1,370 ) $ — Liabilities — (8,372 ) (7,607 ) 1,370 (14,609 ) Total commodity derivatives — (7,090 ) (7,519 ) — (14,609 ) Equity securities 693 — — — 693 $ 693 $ (7,090 ) $ (7,519 ) $ — $ (13,916 ) December 31, 2017 Level 1 Level 2 Level 3 Effect of Netting Net Amounts Presented (In thousands) Financial assets (liabilities): Commodity derivatives: Assets $ — $ 2,137 $ 3,344 $ (4,760 ) $ 721 Liabilities — (8,973 ) (3,550 ) 4,760 (7,763 ) Total commodity derivatives $ — $ (6,836 ) $ (206 ) $ — $ (7,042 ) Equity securities 932 — — — 932 $ 932 $ (6,836 ) $ (206 ) $ — $ (6,110 )
Reconciliations Of Level 3 Fair Value Measurements	The following table is a reconciliation of our level 3 fair value measurements: Net Derivatives Three Months Ended Nine Months Ended September 30, September 30, 2018 2017 2018 2017 (In thousands) Beginning of period $ (6,135 ) $ 4,093 $ (206 ) $ (7,122 ) Total gains or losses (realized and unrealized): Included in earnings (1) (3,700 ) (2,015 ) (12,324 ) 9,102 Settlements 2,316 (592 ) 5,011 (494 ) End of period $ (7,519 ) $ 1,486 $ (7,519 ) $ 1,486 Total gains (losses) for the period included in earnings attributable to the change in unrealized gain relating to assets still held at end of period $ (1,384 ) $ (2,607 ) $ (7,313 ) $ 8,608 _______________________ (1) Commodity derivatives are reported in the Unaudited Condensed Consolidated Income Statements in gain (loss) on derivatives.
Schedule Of Quantitative Information About Unobservable Inputs	The following table provides quantitative information about our Level 3 unobservable inputs at September 30, 2018 : Commodity (1) Fair Value Valuation Technique Unobservable Input Range (In thousands) Oil three-way collars $ (7,607 ) Discounted cash flow Forward commodity price curve $0 - $17.65 Natural gas three-way collars $ 88 Discounted cash flow Forward commodity price curve $0 - $0.12 _______________________ (1) The commodity contracts detailed in this category include non-exchange-traded crude oil and natural gas three-way collars that are valued based on NYMEX. The forward pricing range represents the low and high price expected to be paid or received within the settlement period.

Variable Interest Entity Arra_2

Variable Interest Entity Arrangements (Tables)	9 Months Ended
	Sep. 30, 2018
Variable Interest Entity Arrangements [Abstract]
Schedule of Assets and Liabilities	The carrying value of Superior's assets and liabilities, after eliminations of any intercompany transactions and balances, in the consolidated balance sheets were as follows: September 30, (In thousands) Current assets: Cash and cash equivalents $ 9,039 Accounts receivable 29,991 Prepaid expenses and other 2,756 Total current assets 41,786 Property and equipment: Gas gathering and processing equipment 751,715 Transportation equipment 3,064 754,779 Less accumulated depreciation, depletion, amortization, and impairment 353,476 Net property and equipment 401,303 Other assets 15,411 Total assets $ 458,500 Current liabilities: Accounts payable $ 28,183 Accrued liabilities 3,574 Current portion of other long-term liabilities 6,836 Total current liabilities 38,593 Long-term debt less debt issuance costs — Other long-term liabilities 16,126 Total liabilities $ 54,719

Equity (Tables)

Equity (Tables)	9 Months Ended
	Sep. 30, 2018
Equity [Abstract]
Schedule of Accumulated Other Comprehensive Income	Components of accumulated other comprehensive income (loss) were as follows for the three months ended September 30 : 2018 2017 (In thousands) Unrealized appreciation on securities, before tax $ (51 ) $ 53 Tax benefit (expense) 13 (1) (20 ) Unrealized appreciation on securities, net of tax $ (38 ) $ 33 _______________________ (1) Due to the implementation of ASU 2018-02, the tax rate changed from 37.75% to 24.5%. Components of accumulated other comprehensive income (loss) were as follows for the nine months ended September 30 : 2018 2017 (In thousands) Unrealized appreciation (loss) on securities, before tax $ (239 ) $ 85 Tax benefit (expense) 60 (1) (32 ) Unrealized appreciation (loss) on securities, net of tax $ (179 ) $ 53 _______________________ (1) Due to the implementation of ASU 2018-02, the tax rate changed from 37.75% to 24.5%.
Reclassification Out of Accumulated Other Comprehensive Income	Changes in accumulated other comprehensive income by component, net of tax, for the nine months ended September 30 are as follows: Net Gains on Equity Securities 2018 2017 (In thousands) Balance at December 31, 2017 $ 63 $ — Adjustment due to ASU 2018-02 13 (1) — Balance at January 1: 76 — Unrealized appreciation (loss) before reclassifications (179 ) (1) 53 Amounts reclassified from accumulated other comprehensive income — — Net current-period other comprehensive income (loss) (179 ) 53 Balance at September 30: $ (103 ) $ 53 _______________________ (1) Due to the implementation of ASU 2018-02, the tax rate changed from 37.75% to 24.5%. Changes in accumulated other comprehensive income (loss) by component, net of tax, for the three months ended September 30 are as follows: Net Gains on Equity Securities 2018 2017 (In thousands) Balance at June 30: $ (65 ) $ 20 Unrealized appreciation (loss) before reclassifications (38 ) (1) 33 Amounts reclassified from accumulated other comprehensive income — — Net current-period other comprehensive income (loss) (38 ) 33 Balance at September 30: $ (103 ) $ 53 _______________________ (1) Due to the implementation of ASU 2018-02, the tax rate changed from 37.75% to 24.5%.

Industry Segment Information (T

Industry Segment Information (Tables)	9 Months Ended
	Sep. 30, 2018
Segment Reporting [Abstract]
Industry segment information	The following tables provide certain information about the operations of each of our segments: Three Months Ended September 30, 2018 Oil and Natural Gas Contract Drilling Mid-stream Other Eliminations Total Consolidated (In thousands) Revenues: (1) Oil and natural gas $ 111,623 $ — $ — $ — $ — $ 111,623 Contract drilling — 58,012 — — (7,400 ) 50,612 Gas gathering and processing — — 82,882 — (25,059 ) 57,823 Total revenues 111,623 58,012 82,882 — (32,459 ) 220,058 Expenses: Operating costs: Oil and natural gas 33,400 — — — (1,261 ) 32,139 Contract drilling — 38,246 — — (6,214 ) 32,032 Gas gathering and processing — — 66,932 3,808 (27,606 ) 43,134 Total operating costs 33,400 38,246 66,932 3,808 (35,081 ) 107,305 Depreciation, depletion, and amortization 35,460 14,889 11,265 1,923 — 63,537 Total expenses 68,860 53,135 78,197 5,731 (35,081 ) 170,842 General and administrative — — — 9,278 — 9,278 Gain on disposition of assets (7 ) (230 ) (16 ) — — (253 ) Income (loss) from operations 42,770 5,107 4,701 (15,009 ) 2,622 40,191 Loss on derivatives — — — (4,385 ) — (4,385 ) Interest, net — — (381 ) (7,564 ) — (7,945 ) Other — — — 3,814 (3,808 ) 6 Income (loss) before income taxes $ 42,770 $ 5,107 $ 4,320 $ (23,144 ) $ (1,186 ) $ 27,867 _______________________ (1) The revenues for oil and natural gas occur at a point in time. The revenues for contract drilling and gas gathering and processing occur over time. Three Months Ended September 30, 2017 Oil and Natural Gas Contract Drilling Mid-stream Other Eliminations Total Consolidated (In thousands) Revenues: Oil and natural gas $ 85,470 $ — $ — $ — $ — $ 85,470 Contract drilling — 55,588 — — (3,969 ) 51,619 Gas gathering and processing — — 69,057 — (17,658 ) 51,399 Total revenues 85,470 55,588 69,057 — (21,627 ) 188,488 Expenses: Operating costs: Oil and natural gas 35,082 — — — (1,171 ) 33,911 Contract drilling — 38,115 — — (3,368 ) 34,747 Gas gathering and processing — — 54,602 — (16,486 ) 38,116 Total operating costs 35,082 38,115 54,602 — (21,025 ) 106,774 Depreciation, depletion, and amortization 26,460 15,280 10,880 1,913 — 54,533 Total expenses 61,542 53,395 65,482 1,913 (21,025 ) 161,307 General and administrative expense — — — 9,235 — 9,235 (Gain) loss on disposition of assets 1 (68 ) (14 ) — — (81 ) Income (loss) from operations 23,927 2,261 3,589 (11,148 ) (602 ) 18,027 Loss on derivatives — — — (2,614 ) — (2,614 ) Interest, net — — — (9,944 ) — (9,944 ) Other — — — 5 — 5 Income (loss) before income taxes $ 23,927 $ 2,261 $ 3,589 $ (23,701 ) $ (602 ) $ 5,474 Nine Months Ended September 30, 2018 Oil and Natural Gas Contract Drilling Mid-stream Other Eliminations Total Consolidated (In thousands) Revenues: (1) Oil and natural gas $ 317,040 $ — $ — $ — $ — $ 317,040 Contract drilling — 161,489 — — (17,962 ) 143,527 Gas gathering and processing — — 232,938 — (65,012 ) 167,926 Total revenues 317,040 161,489 232,938 — (82,974 ) 628,493 Expenses: Operating costs: Oil and natural gas 104,234 — — — (3,715 ) 100,519 Contract drilling — 111,121 — — (15,528 ) 95,593 Gas gathering and processing — — 185,738 7,384 (68,681 ) 124,441 Total operating costs 104,234 111,121 185,738 7,384 (87,924 ) 320,553 Depreciation, depletion, and amortization 97,797 41,927 33,493 5,759 — 178,976 Total expenses 202,031 153,048 219,231 13,143 (87,924 ) 499,529 General and administrative expense — — — 28,752 — 28,752 Gain on disposition of assets (136 ) (314 ) (95 ) (30 ) — (575 ) Income (loss) from operations 115,145 8,755 13,802 (41,865 ) 4,950 100,787 Loss on derivatives — — — (25,608 ) — (25,608 ) Interest, net — — (834 ) (24,844 ) — (25,678 ) Other — — — 7,401 (7,384 ) 17 Income (loss) before income taxes $ 115,145 $ 8,755 $ 12,968 $ (84,916 ) $ (2,434 ) $ 49,518 _______________________ (1) The revenues for oil and natural gas occur at a point in time. The revenues for contract drilling and gas gathering and processing occur over time. Nine Months Ended September 30, 2017 Oil and Natural Gas Contract Drilling Mid-stream Other Eliminations Total Consolidated (In thousands) Revenues: Oil and natural gas $ 256,241 $ — $ — $ — $ — $ 256,241 Contract drilling — 137,617 — — (9,558 ) 128,059 Gas gathering and processing — — 198,632 — (48,139 ) 150,493 Total revenues 256,241 137,617 198,632 — (57,697 ) 534,793 Expenses: Operating costs: Oil and natural gas 99,349 — — — (3,476 ) 95,873 Contract drilling — 99,794 — — (8,581 ) 91,213 Gas gathering and processing — — 156,525 — (44,663 ) 111,862 Total operating costs 99,349 99,794 156,525 — (56,720 ) 298,948 Depreciation, depletion, and amortization 71,544 41,896 32,547 5,558 — 151,545 Total expenses 170,893 141,690 189,072 5,558 (56,720 ) 450,493 General and administrative expense — — — 26,902 — 26,902 Gain on disposition of assets (176 ) (106 ) (58 ) (813 ) — (1,153 ) Income (loss) from operations 85,524 (3,967 ) 9,618 (31,647 ) (977 ) 58,551 Gain on derivatives — — — 21,019 — 21,019 Interest, net — — — (28,807 ) — (28,807 ) Other — — — 14 — 14 Income (loss) before income taxes $ 85,524 $ (3,967 ) $ 9,618 $ (39,421 ) $ (977 ) $ 50,777

Supplemental Condensed Consol_2

Supplemental Condensed Consolidating Financial Information (Tables)	9 Months Ended
	Sep. 30, 2018
Supplemental Condensed Consolidated Financial Information [Abstract]
Condensed Consolidating Balance Sheets (Unaudited)	Condensed Consolidating Balance Sheets (Unaudited) September 30, 2018 Parent Combined Guarantor Subsidiaries Combined Non-Guarantor Subsidiaries Consolidating Adjustments Total Consolidated (In thousands) ASSETS Current assets: Cash and cash equivalents $ 82,267 $ 251 $ 9,039 $ — $ 91,557 Accounts receivable, net of allowance for doubtful accounts of $2,450 (Guarantor of $1,245 and Non-Guarantor of $1,205) 1,374 92,078 28,671 — 122,123 Materials and supplies — 505 — — 505 Current derivative asset — — — — — Prepaid expenses and other 3,125 3,538 2,756 — 9,419 Total current assets 86,766 96,372 40,466 — 223,604 Property and equipment: Oil and natural gas properties on the full cost method: Proved properties — 5,901,661 — — 5,901,661 Unproved properties not being amortized — 332,886 — — 332,886 Drilling equipment — 1,632,540 — — 1,632,540 Gas gathering and processing equipment — — 751,715 — 751,715 Saltwater disposal systems — 67,074 — — 67,074 Corporate land and building — 59,081 — — 59,081 Transportation equipment 9,273 16,766 3,064 — 29,103 Other 28,506 28,244 — — 56,750 37,779 8,038,252 754,779 — 8,830,810 Less accumulated depreciation, depletion, amortization, and impairment 25,922 5,945,762 353,476 — 6,325,160 Net property and equipment 11,857 2,092,490 401,303 — 2,505,650 Intercompany receivable 907,907 — — (907,907 ) — Goodwill — 62,808 — — 62,808 Investments 1,248,309 1,500 — (1,248,309 ) 1,500 Other assets 5,605 6,186 15,412 — 27,203 Total assets $ 2,260,444 $ 2,259,356 $ 457,181 $ (2,156,216 ) $ 2,820,765 September 30, 2018 Parent Combined Guarantor Subsidiaries Combined Non-Guarantor Subsidiaries Consolidating Adjustments Total Consolidated (In thousands) LIABILITIES AND SHAREHOLDERS’ EQUITY Current liabilities: Accounts payable $ 28,116 $ 90,543 $ 24,893 $ — $ 143,552 Accrued liabilities 36,444 26,583 4,716 — 67,743 Income taxes payable 1,051 — — — 1,051 Current derivative liability 13,067 — — — 13,067 Current portion of other long-term liabilities 966 6,348 6,836 — 14,150 Total current liabilities 79,644 123,474 36,445 — 239,563 Intercompany debt — 906,296 1,086 (907,382 ) — Bonds payable less debt issuance costs 643,921 — — — 643,921 Non-current derivative liabilities 1,542 — — — 1,542 Other long-term liabilities 12,790 72,494 16,126 — 101,410 Deferred income taxes 54,707 110,257 — — 164,964 Shareholders’ equity: Preferred stock, $1.00 par value, 5,000,000 shares authorized, none issued — — — — — Common stock, $.20 par value, 175,000,000 shares authorized, 54,063,705 shares issued 10,414 — — — 10,414 Capital in excess of par value 626,746 45,921 197,042 (242,963 ) 626,746 Contributions from Unit — — 525 (525 ) — Accumulated other comprehensive loss — (103 ) — — (103 ) Retained earnings 830,680 1,001,017 4,329 (1,005,346 ) 830,680 Total shareholders’ equity attributable to Unit Corporation 1,467,840 1,046,835 201,896 (1,248,834 ) 1,467,737 Non-controlling interests in consolidated subsidiaries — — 201,628 — 201,628 Total shareholders' equity 1,467,840 1,046,835 403,524 (1,248,834 ) 1,669,365 Total liabilities and shareholders’ equity $ 2,260,444 $ 2,259,356 $ 457,181 $ (2,156,216 ) $ 2,820,765 December 31, 2017 Parent Combined Guarantor Subsidiaries Combined Non-Guarantor Subsidiaries Consolidating Adjustments Total Consolidated (In thousands) ASSETS Current assets: Cash and cash equivalents $ 510 $ 191 $ — $ — $ 701 Accounts receivable, net of allowance for doubtful accounts of $2,450 (Guarantor of $1,245 and Non-Guarantor of $1,205) 154 83,442 27,916 — 111,512 Materials and supplies — 505 — — 505 Current derivative asset 721 — — — 721 Prepaid expenses and other 2,986 2,370 877 — 6,233 Total current assets 4,371 86,508 28,793 — 119,672 Property and equipment: Oil and natural gas properties on the full cost method: Proved properties — 5,712,813 — — 5,712,813 Unproved properties not being amortized — 296,764 — — 296,764 Drilling equipment — 1,593,611 — — 1,593,611 Gas gathering and processing equipment — — 726,236 — 726,236 Saltwater disposal systems — 62,618 — — 62,618 Corporate land and building — 59,080 — — 59,080 Transportation equipment 9,270 17,423 2,938 — 29,631 Other 28,039 25,400 — — 53,439 37,309 7,767,709 729,174 — 8,534,192 Less accumulated depreciation, depletion, amortization, and impairment 21,268 5,807,757 322,425 — 6,151,450 Net property and equipment 16,041 1,959,952 406,749 — 2,382,742 Intercompany receivable 1,155,725 — — (1,155,725 ) — Goodwill — 62,808 — — 62,808 Investments 1,044,709 1,500 — (1,044,709 ) 1,500 Other assets 5,373 6,328 3,029 — 14,730 Total assets $ 2,226,219 $ 2,117,096 $ 438,571 $ (2,200,434 ) $ 2,581,452 December 31, 2017 Parent Combined Guarantor Subsidiaries Combined Non-Guarantor Subsidiaries Consolidating Adjustments Total Consolidated (In thousands) LIABILITIES AND SHAREHOLDERS’ EQUITY Current liabilities: Accounts payable $ 13,124 $ 81,334 $ 18,190 $ — $ 112,648 Accrued liabilities 26,165 19,134 3,224 — 48,523 Current derivative liability 7,763 — — — 7,763 Current portion of other long-term liabilities 657 8,501 3,844 — 13,002 Total current liabilities 47,709 108,969 25,258 — 181,936 Intercompany debt — 870,582 285,143 (1,155,725 ) — Long-term debt 178,000 — — — 178,000 Bonds payable less debt issuance costs 642,276 — — — 642,276 Other long-term liabilities 11,257 77,566 11,380 — 100,203 Deferred income taxes 1,480 85,443 46,554 — 133,477 Shareholders’ equity: Preferred stock, $1.00 par value, 5,000,000 shares authorized, none issued — — — — — Common stock, $.20 par value, 175,000,000 shares authorized, 52,880,134 shares issued 10,280 — — — 10,280 Capital in excess of par value 535,815 45,921 15,549 (61,470 ) 535,815 Accumulated other comprehensive income — 63 — — 63 Retained earnings 799,402 928,552 54,687 (983,239 ) 799,402 Total shareholders’ equity attributable to Unit Corporation 1,345,497 974,536 70,236 (1,044,709 ) 1,345,560 Non-controlling interests in consolidated subsidiaries — — — — — Total shareholders' equity 1,345,497 974,536 70,236 (1,044,709 ) 1,345,560 Total liabilities and shareholders’ equity $ 2,226,219 $ 2,117,096 $ 438,571 $ (2,200,434 ) $ 2,581,452
Condensed Consolidating Statements of Income (Unaudited)	Condensed Consolidating Statements of Income (Unaudited) Three Months Ended September 30, 2018 Parent Combined Guarantor Subsidiaries Combined Non-Guarantor Subsidiaries Consolidating Adjustments Total Consolidated (In thousands) Revenues $ — $ 169,635 $ 82,882 $ (32,459 ) $ 220,058 Expenses: Operating costs — 71,646 66,932 (31,273 ) 107,305 Depreciation, depletion, and amortization 1,923 50,349 11,265 — 63,537 General and administrative — 9,252 26 — 9,278 Gain on disposition of assets — (237 ) (16 ) — (253 ) Total operating costs 1,923 131,010 78,207 (31,273 ) 179,867 Income from operations (1,923 ) 38,625 4,675 (1,186 ) 40,191 Interest, net (7,564 ) — (381 ) — (7,945 ) Loss on derivatives (4,385 ) — — — (4,385 ) Other, net 6 (1 ) 1 — 6 Income (loss) before income taxes (13,866 ) 38,624 4,295 (1,186 ) 27,867 Income tax expense (benefit) (3,688 ) 9,839 593 — 6,744 Equity in net earnings from investment in subsidiaries, net of taxes 29,077 — — (29,077 ) — Net income 18,899 28,785 3,702 (30,263 ) 21,123 Less: net income attributable to non-controlling interest — — 2,224 — 2,224 Net income attributable to Unit Corporation $ 18,899 $ 28,785 $ 1,478 $ (30,263 ) $ 18,899 Three Months Ended September 30, 2017 Parent Combined Guarantor Subsidiaries Combined Non-Guarantor Subsidiaries Consolidating Adjustments Total Consolidated (In thousands) Revenues $ — $ 141,058 $ 69,057 $ (21,627 ) $ 188,488 Expenses: Operating costs — 73,197 54,603 (21,026 ) 106,774 Depreciation, depletion, and amortization 1,913 41,740 10,880 — 54,533 General and administrative — 7,083 2,152 — 9,235 Gain on disposition of assets — (67 ) (14 ) — (81 ) Total operating costs 1,913 121,953 67,621 (21,026 ) 170,461 Income (loss) from operations (1,913 ) 19,105 1,436 (601 ) 18,027 Interest, net (9,776 ) — (168 ) — (9,944 ) Loss on derivatives (2,614 ) — — — (2,614 ) Other, net 5 — — — 5 Income (loss) before income taxes (14,298 ) 19,105 1,268 (601 ) 5,474 Income tax expense (benefit) (5,626 ) 7,003 392 — 1,769 Equity in net earnings from investment in subsidiaries, net of taxes 12,377 — — (12,377 ) — Net income 3,705 12,102 876 (12,978 ) 3,705 Less: net income attributable to non-controlling interest — — — — — Net income attributable to Unit Corporation $ 3,705 $ 12,102 $ 876 $ (12,978 ) $ 3,705 Nine Months Ended September 30, 2018 Parent Combined Guarantor Subsidiaries Combined Non-Guarantor Subsidiaries Consolidating Adjustments Total Consolidated (In thousands) Revenues $ — $ 478,529 $ 232,938 $ (82,974 ) $ 628,493 Expenses: Operating costs — 215,355 185,738 (80,540 ) 320,553 Depreciation, depletion, and amortization 5,759 139,724 33,493 — 178,976 General and administrative — 26,136 2,616 — 28,752 Gain on disposition of assets (30 ) (450 ) (95 ) — (575 ) Total operating costs 5,729 380,765 221,752 (80,540 ) 527,706 Income (loss) from operations (5,729 ) 97,764 11,186 (2,434 ) 100,787 Interest, net (24,844 ) — (834 ) — (25,678 ) Loss on derivatives (25,608 ) — — — (25,608 ) Other, net 17 — — — 17 Income (loss) before income taxes (56,164 ) 97,764 10,352 (2,434 ) 49,518 Income tax expense (benefit) (14,356 ) 25,299 1,437 — 12,380 Equity in net earnings from investment in subsidiaries, net of tax 74,360 — — (74,360 ) — Net income 32,552 72,465 8,915 (76,794 ) 37,138 Less: net income attributable to non-controlling interest — — 4,586 — 4,586 Net income attributable to Unit Corporation $ 32,552 $ 72,465 $ 4,329 $ (76,794 ) $ 32,552 Nine Months Ended September 30, 2017 Parent Combined Guarantor Subsidiaries Combined Non-Guarantor Subsidiaries Consolidating Adjustments Total Consolidated (In thousands) Revenues $ — $ 393,858 $ 198,632 $ (57,697 ) $ 534,793 Expenses: Operating costs — 199,143 156,525 (56,720 ) 298,948 Depreciation, depletion, and amortization 5,558 113,440 32,547 — 151,545 General and administrative — 20,880 6,022 — 26,902 Gain on disposition of assets (813 ) (282 ) (58 ) — (1,153 ) Total operating costs 4,745 333,181 195,036 (56,720 ) 476,242 Income (loss) from operations (4,745 ) 60,677 3,596 (977 ) 58,551 Interest, net (28,276 ) — (531 ) — (28,807 ) Gain on derivatives 21,019 — — — 21,019 Other, net 14 — — — 14 Income (loss) before income taxes (11,988 ) 60,677 3,065 (977 ) 50,777 Income tax expense (benefit) (4,895 ) 25,357 1,622 — 22,084 Equity in net earnings from investment in subsidiaries, net of tax 35,786 — — (35,786 ) — Net income 28,693 35,320 1,443 (36,763 ) 28,693 Less: net income attributable to non-controlling interest — — — — — Net income attributable to Unit Corporation $ 28,693 $ 35,320 $ 1,443 $ (36,763 ) $ 28,693
Condensed Consolidating Statements of Comprehensive Income (Unaudited)	Condensed Consolidating Statements of Comprehensive Income (Unaudited) Three Months Ended September 30, 2018 Parent Combined Guarantor Subsidiaries Combined Non-Guarantor Subsidiaries Consolidating Adjustments Total Consolidated (In thousands) Net income $ 18,899 $ 28,785 $ 3,702 $ (30,263 ) $ 21,123 Other comprehensive income, net of taxes: Unrealized loss on securities, net of tax ($13) — (38 ) — — (38 ) Comprehensive income 18,899 28,747 3,702 (30,263 ) 21,085 Less: Comprehensive income attributable to non-controlling interests — — 2,224 — 2,224 Comprehensive income attributable to Unit Corporation $ 18,899 $ 28,747 $ 1,478 $ (30,263 ) $ 18,861 Three Months Ended September 30, 2017 Parent Combined Guarantor Subsidiaries Combined Non-Guarantor Subsidiaries Consolidating Adjustments Total Consolidated (In thousands) Net income $ 3,705 $ 12,102 $ 876 $ (12,978 ) $ 3,705 Other comprehensive income, net of taxes: Unrealized gain on securities, net of tax of $20 — 33 — — 33 Comprehensive income 3,705 12,135 876 (12,978 ) 3,738 Less: Comprehensive income attributable to non-controlling interests — — — — — Comprehensive income attributable to Unit Corporation $ 3,705 $ 12,135 $ 876 $ (12,978 ) $ 3,738 Nine Months Ended September 30, 2018 Parent Combined Guarantor Subsidiaries Combined Non-Guarantor Subsidiaries Consolidating Adjustments Total Consolidated (In thousands) Net income $ 32,552 $ 72,465 $ 8,915 $ (76,794 ) $ 37,138 Other comprehensive income, net of taxes: Unrealized loss on securities, net of tax of ($60) — (179 ) — — (179 ) Comprehensive income 32,552 72,286 8,915 (76,794 ) 36,959 Less: Comprehensive income attributable to non-controlling interests — — 4,586 — 4,586 Comprehensive income attributable to Unit Corporation $ 32,552 $ 72,286 $ 4,329 $ (76,794 ) $ 32,373 Nine Months Ended September 30, 2017 Parent Combined Guarantor Subsidiaries Combined Non-Guarantor Subsidiaries Consolidating Adjustments Total Consolidated (In thousands) Net income $ 28,693 $ 35,320 $ 1,443 $ (36,763 ) $ 28,693 Other comprehensive income, net of taxes: Unrealized gain on securities, net of tax of $32 — 53 — — 53 Comprehensive income 28,693 35,373 1,443 (36,763 ) 28,746 Less: Comprehensive income attributable to non-controlling interests — — — — — Comprehensive income attributable to Unit Corporation $ 28,693 $ 35,373 $ 1,443 $ (36,763 ) $ 28,746
Condensed Consolidating Statements of Cash Flows (Unaudited)	Condensed Consolidating Statements of Cash Flows (Unaudited) Nine Months Ended September 30, 2018 Parent Combined Guarantor Subsidiaries Combined Non-Guarantor Subsidiaries Consolidating Adjustments Total Consolidated (In thousands) OPERATING ACTIVITIES: Net cash provided by (used in) operating activities (103,436 ) 215,350 (3,984 ) 128,605 236,535 INVESTING ACTIVITIES: Capital expenditures 22 (275,434 ) (28,642 ) — (304,054 ) Producing properties and other acquisitions — (769 ) — — (769 ) Proceeds from disposition of assets 30 25,199 87 — 25,316 Net cash provided by (used in) investing activities 52 (251,004 ) (28,555 ) — (279,507 ) FINANCING ACTIVITIES: Borrowings under credit agreement 69,200 — 2,000 — 71,200 Payments under credit agreement (247,200 ) — (2,000 ) — (249,200 ) Intercompany borrowings (advances), net 248,343 35,714 (155,977 ) (128,080 ) — Payments on capitalized leases — — (2,869 ) — (2,869 ) Proceeds from investments of non-controlling interest 102,958 — 197,042 — 300,000 Contributions from Unit — — 525 (525 ) — Transaction costs associated with sale of non-controlling interest (2,303 ) — — — (2,303 ) Book overdrafts 14,143 — 2,857 — 17,000 Net cash provided by financing activities 185,141 35,714 41,578 (128,605 ) 133,828 Net increase in cash and cash equivalents 81,757 60 9,039 — 90,856 Cash and cash equivalents, beginning of period 510 191 — — 701 Cash and cash equivalents, end of period $ 82,267 $ 251 $ 9,039 $ — $ 91,557 Nine Months Ended September 30, 2017 Parent Combined Guarantor Subsidiaries Combined Non-Guarantor Subsidiaries Consolidating Adjustments Total Consolidated (In thousands) OPERATING ACTIVITIES: Net cash provided by operating activities 822 149,963 34,007 — 184,792 INVESTING ACTIVITIES: Capital expenditures (3,595 ) (152,055 ) (11,742 ) — (167,392 ) Producing properties and other acquisitions — (55,429 ) — — (55,429 ) Proceeds from disposition of assets 955 19,124 58 — 20,137 Other — (1,500 ) — — (1,500 ) Net cash used in investing activities (2,640 ) (189,860 ) (11,684 ) — (204,184 ) FINANCING ACTIVITIES: Borrowings under credit agreement 251,401 — — — 251,401 Payments under credit agreement (250,100 ) — — — (250,100 ) Intercompany borrowings (advances), net (20,483 ) 39,839 (19,356 ) — — Payments on capitalized leases — — (2,967 ) — (2,967 ) Proceeds from common stock issued, net of issue costs 18,623 — — — 18,623 Book overdrafts 2,364 — — — 2,364 Net cash provided by (used in) financing activities 1,805 39,839 (22,323 ) — 19,321 Net decrease in cash and cash equivalents (13 ) (58 ) — — (71 ) Cash and cash equivalents, beginning of period 517 376 — — 893 Cash and cash equivalents, end of period $ 504 $ 318 $ — $ — $ 822

Basis of Preparation and Pres_2

Basis of Preparation and Presentation (Narrative) (Details)	9 Months Ended	12 Months Ended
	Sep. 30, 2018	Dec. 31, 2017
Basis of Preparation and Presentation [Abstract]
Consolidation, Variable Interest Entity, Policy [Policy Text Block]	We consolidate the activities of Superior Pipeline Company, L.L.C. (Superior), a 50/50 joint venture between Unit Corporation and SP Investor Holdings, LLC, which qualifies as a VIE under generally accepted accounting principles in the United States (GAAP). We have concluded that we are the primary beneficiary of the VIE, as defined in the accounting standards, since we have the power, through our 50% ownership, to direct those activities that most significantly affect the economic performance of Superior as further described in Note 13 – Variable Interest Entity Arrangements.
Federal Statutory Income Tax Rate, Percent	24.50%	37.75%

Revenue from Contracts with C_2

Revenue from Contracts with Customers (Revenue Impact of the Adoption of ASC606) (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 2017
Adoption of ASC606 [Line Items]
Oil and natural gas revenues	$ 111,623	$ 85,470	$ 317,040	$ 256,241
Oil and natural gas operating costs	32,139	33,911	100,519	95,873
Oil and natural gas gross profit	79,484		216,521
Gas gathering and processing revenues	57,823	51,399	167,926	150,493
Deferred tax expense	6,744	1,769	12,380	22,084
Net income	21,123	$ 3,705	37,138	$ 28,693
Adjustments due to ASC606 [Member]
Adoption of ASC606 [Line Items]
Oil and natural gas revenues	(5,200)		(12,102)
Oil and natural gas operating costs	(5,200)		(12,102)
Oil and natural gas gross profit	0		0
Gas gathering and processing revenues	1,300		3,671
Deferred tax expense	318		899
Net income	982		2,772
Amounts without the Adoption of ASC606 [Member]
Adoption of ASC606 [Line Items]
Oil and natural gas revenues	116,823		329,142
Oil and natural gas operating costs	37,339		112,621
Oil and natural gas gross profit	79,484		216,521
Gas gathering and processing revenues	56,523		164,255
Deferred tax expense	6,426		11,481
Net income	$ 20,141		$ 34,366

Revenue from Contracts with C_3

Revenue from Contracts with Customers (Balance Sheet Impact of the Adoption of ASC606) (Details) - USD ($) $ in Thousands	Sep. 30, 2018	Jan. 01, 2018	Dec. 31, 2017
ASSETS
Prepaid expenses and other	$ 9,419		$ 6,233
Other assets	28,703	$ 27,028	16,230
LIABILITIES AND SHAREHOLDERS' EQUITY
Current portion of other long-term liabilities	14,150	15,750	13,002
Other long-term liabilities	101,410	109,940	100,203
Deferred income taxes	164,964	133,064	133,477
Retained earnings	830,680	798,128	$ 799,402
Mid-Stream [Member] | Adjustments due to ASC606 [Member]
ASSETS
Prepaid expenses and other	206
Other assets	12,383	10,798
LIABILITIES AND SHAREHOLDERS' EQUITY
Current portion of other long-term liabilities	2,874	2,748
Other long-term liabilities	7,731	9,737
Deferred income taxes	486	(413)
Retained earnings	1,498
Impact of Restatement on Opening Retained Earnings, Net of Tax		$ (1,274)
Mid-Stream [Member] | Amounts without the Adoption of ASC606 [Member]
ASSETS
Prepaid expenses and other	9,213
Other assets	16,320
LIABILITIES AND SHAREHOLDERS' EQUITY
Current portion of other long-term liabilities	11,276
Other long-term liabilities	93,679
Deferred income taxes	164,478
Retained earnings	$ 829,182

Revenue from Contracts with C_4

Revenue from Contracts with Customers (Revenue, Remaining Performance Obligation) (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 2017
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Net income	$ 21,123	$ 3,705	$ 37,138	$ 28,693
Minimum [Member] | Mid-Stream [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining Term of Contract			4 years
Maximum [Member] | Mid-Stream [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining Term of Contract			5 years
Demand fee contracts [Member] | Mid-Stream [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining Impact to Revenue	(1,983)		$ (1,983)
Demand fee contracts [Member] | Mid-Stream [Member] | October - December 2018
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining Impact to Revenue	1,299		1,299
Demand fee contracts [Member] | Mid-Stream [Member] | 2019
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining Impact to Revenue	2,632		2,632
Demand fee contracts [Member] | Mid-Stream [Member] | 2020
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining Impact to Revenue	(3,781)		(3,781)
Demand fee contracts [Member] | Mid-Stream [Member] | 2021
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining Impact to Revenue	(3,507)		(3,507)
Demand fee contracts [Member] | Mid-Stream [Member] | 2022
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining Impact to Revenue	$ 1,374		$ 1,374

Revenue from Contracts with C_5

Revenue from Contracts with Customers (Contract with Customer, Asset and Liability) (Details) - USD ($) $ in Thousands	9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017	Jan. 01, 2018	Dec. 31, 2017
Adoption of ASC606 [Line Items]
Contract liability	$ 10,605			$ 0
Change in contract assets (liabilities), net	(3,671)	$ 0
Mid-Stream [Member]
Adoption of ASC606 [Line Items]
Contract assets	12,589		$ 10,798
Change in contract assets	1,791
Contract liability	10,605		12,485
Change in contract liabilities	(1,880)
Contract assets (liabilities), net	1,984		$ (1,687)
Change in contract assets (liabilities), net	$ (3,671)

Revenue from Contracts with C_6

Revenue from Contracts with Customer (Narrative) (Details) $ in Thousands	3 Months Ended			9 Months Ended
	Sep. 30, 2018USD ($)		Sep. 30, 2017USD ($)	Sep. 30, 2018USD ($)contract		Sep. 30, 2017USD ($)	Jan. 01, 2018USD ($)	Dec. 31, 2017USD ($)
Segment Reporting Information [Line Items]
Retained earnings	$ 830,680			$ 830,680			$ 798,128	$ 799,402
Gas gathering and processing revenues	57,823		$ 51,399	167,926		$ 150,493
Net income	21,123		3,705	37,138		28,693
Income from operations	40,191		18,027	$ 100,787		58,551
Drilling [Member]
Segment Reporting Information [Line Items]
Revenue Satisfied over Time, Method Used				At inception, the total transaction price will be estimated to include any applicable fixed consideration, unconstrained variable consideration (estimated day rate mobilization and demobilization revenue, estimated operating day rate revenue to be earned over the contract term, expected bonuses (if material and can be reasonably estimated without significant reversal), and penalties (if material and can be reasonably estimated without significant reversal)). Allocation rules under this new standard allow us to recognize revenues associated with our drilling contacts in materially the same manner as under the previous revenue accounting standard. A contract liability will be recorded for consideration received before the corresponding transfer of services. Those liabilities will generally only arise in relation to upfront mobilization fees paid in advance and are allocated/recognized over the entire performance obligation. Such balances will be amortized over the recognition period based on the same method of measure used for revenue.
Number of Contracts, Daywork | contract				34
Revenue, Practical Expedient, Initial Application and Transition, Qualitative Assessment				The majority of our drilling contracts have an original term of less than one year; however, the remaining performance obligations under the contracts that have a longer duration are not material.
Gas gathering and processing revenues	0	[1]	0	$ 0	[2]	0
Oil and Natural Gas [Member]
Segment Reporting Information [Line Items]
Revenue Satisfied at Point in Time, Transfer of Control				Revenues from sales we make are recognized when our customer obtains control of the sold product. For sales to other mid-stream and downstream oil and gas companies, this would occur at a point in time, typically on delivery to the customer.
Gas gathering and processing revenues	0	[1]	0	$ 0	[2]	0
Mid-Stream [Member]
Segment Reporting Information [Line Items]
Revenue Satisfied over Time, Method Used				Contract terms range from a single month to terms spanning a decade or more, some include evergreen provisions. Fees for mid-stream services (gathering, transportation, processing) are performance obligations and meet the criteria of over time recognition which could be considered a series of distinct performance obligations that represents one overall performance obligation of gas gathering and processing services.
Revenue, Practical Expedient, Initial Application and Transition, Qualitative Assessment				As stated previously, the contract term for mid-stream services is typically longer than one year. However, based on the guidance at 606-10-32-40, we determined some of the variable payment in mid-stream service agreements specifically relates to the entity’s efforts to satisfy the performance obligation and that “allocating the variable amount entirely to the distinct good or service is consistent with the allocation objective in paragraph 606-10-32-28.” Therefore, the practical expedient relates to this variable consideration: the commodity fee and the gathering fee.
Gas gathering and processing revenues	82,882	[1]	$ 69,057	$ 232,938	[2]	$ 198,632
Minimum [Member] | Drilling [Member]
Segment Reporting Information [Line Items]
Contract Duration				6 months
Number of Days for Drilling of Wells				10 days
Minimum [Member] | Mid-Stream [Member]
Segment Reporting Information [Line Items]
Contract Duration				5 years
Remaining Term of Contract				4 years
Maximum [Member] | Drilling [Member]
Segment Reporting Information [Line Items]
Contract Duration				3 years
Number of Days for Drilling of Wells				90 days
Maximum [Member] | Mid-Stream [Member]
Segment Reporting Information [Line Items]
Contract Duration				10 years
Remaining Term of Contract				5 years
Short-term Contract with Customer [Member] | Drilling [Member]
Segment Reporting Information [Line Items]
Contract Duration				2 months
Long-term Contract with Customer [Member] | Drilling [Member]
Segment Reporting Information [Line Items]
Contract Duration				3 years
Number of Contracts, Daywork | contract				21
Adjustments due to ASC606 [Member]
Segment Reporting Information [Line Items]
Gas gathering and processing revenues	1,300			$ 3,671
Net income	982			2,772
Adjustments due to ASC606 [Member] | Drilling [Member]
Segment Reporting Information [Line Items]
Retained earnings							0
Adjustments due to ASC606 [Member] | Oil and Natural Gas [Member]
Segment Reporting Information [Line Items]
Retained earnings							0
Net income	0			0
Income from operations	0			0
Adjustments due to ASC606 [Member] | Mid-Stream [Member]
Segment Reporting Information [Line Items]
Retained earnings	$ 1,498			$ 1,498
Adjustment to opening retained earnings, before tax							(1,687)
Adjustment to opening retained earnings, after tax							$ (1,274)
Gathering service contracts [Member] | Minimum [Member] | Mid-Stream [Member]
Segment Reporting Information [Line Items]
Remaining Term of Contract				1 year
Gathering service contracts [Member] | Maximum [Member] | Mid-Stream [Member]
Segment Reporting Information [Line Items]
Remaining Term of Contract				15 years
[1]	The revenues for oil and natural gas occur at a point in time. The revenues for contract drilling and gas gathering and processing occur over time.
[2]	The revenues for oil and natural gas occur at a point in time. The revenues for contract drilling and gas gathering and processing occur over time.

Divestitures (Narrative) (Detai

Divestitures (Narrative) (Details) - USD ($) $ in Millions	Apr. 03, 2018	Sep. 30, 2018	Sep. 30, 2017
Divestitures [Line Items]
Proceeds from non-core oil and natural gas asset sales, net of related expenses		$ 22.3	$ 18
Ownership interest in Superior Pipeline Company, L.L.C. [Member]
Divestitures [Line Items]
Ownership interest sold	50.00%
Proceeds from sale of non-controlling interest	$ 300

Earnings Per Share (Schedule of

Earnings Per Share (Schedule of Earnings Per Share) (Details) - USD ($) $ / shares in Units, shares in Thousands, $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 2017
Earnings Per Share [Abstract]
Earnings of basic earnings attributable to Unit Corporation per common share	$ 18,899	$ 3,705	$ 32,552	$ 28,693
Income of effect of dilutive stock options, restricted stock, and stock appreciation rights (SARs)	0	0	0	0
Earnings of diluted income attributable to Unit Corporation per common share	$ 18,899	$ 3,705	$ 32,552	$ 28,693
Weighted shares of basic earnings attributable to Unit Corporation per common share	52,068	51,386	51,951	51,019
Weighted shares of effect of dilutive stock options, restricted stock, and stock appreciation rights (SARs)	1,072	586	808	550
Weighted shares of diluted earnings attributable to Unit Corporation per common share	53,140	51,972	52,759	51,569
Per-Share amount of basic earnings attributable to Unit Corporation per common share	$ 0.36	$ 0.07	$ 0.63	$ 0.56
Per-Share amount of effect of dilutive stock options, restricted stock, and stock appreciation rights (SARs)	0	0	(0.01)	0
Per-Share amount of diluted earnings attributable to Unit Corporation per common share	$ 0.36	$ 0.07	$ 0.62	$ 0.56

Earnings Per Share (Schedule _2

Earnings Per Share (Schedule of Antidilutive Securities Excluded From Computation of Earnings Per Share) (Details) - Stock options and SARs - $ / shares	3 Months Ended		9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 2017
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Antidilutive securities excluded from computation of earnings per share	66,500	178,755	66,500	178,755
Average exercise price	$ 44.42	$ 47.75	$ 44.42	$ 47.75

Accrued Liabilities (Accrued Li

Accrued Liabilities (Accrued Liabilities) (Details) - USD ($) $ in Thousands	Sep. 30, 2018	Dec. 31, 2017
Accrued Liabilities [Abstract]
Employee costs	$ 17,880	$ 19,521
Interest payable	17,446	6,745
Lease operating expenses	11,474	11,819
Taxes	10,317	3,404
Derivative settlements	3,383	0
Third-party credits	2,099	2,240
Other	5,144	4,794
Total accrued liabilities	$ 67,743	$ 48,523

Long-Term Debt And Other Long_3

Long-Term Debt And Other Long-Term Liabilities (Long-Term Debt) (Details) - USD ($) $ in Thousands	9 Months Ended
	Sep. 30, 2018	Dec. 31, 2017
Debt Instrument [Line Items]
6.625% senior subordinated notes due 2021	$ 650,000	$ 650,000
Total principal amount	650,000	828,000
Less: unamortized discount	(1,780)	(2,234)
Less: debt issuance costs, net	(4,299)	(5,490)
Total long-term debt	$ 643,921	820,276
Interest percentage of senior subordinated notes	6.625%
Debt instrument maturity date	May 15, 2021
6.625% Senior Subordinated Notes Due 2021 [Member]
Debt Instrument [Line Items]
6.625% senior subordinated notes due 2021	$ 650,000
Unit Credit Agreement [Member]
Debt Instrument [Line Items]
Credit agreement	$ 0	$ 178,000
Revolving credit facility interest rate	0.00%	3.40%
Superior Credit Agreement [Member]
Debt Instrument [Line Items]
Credit agreement	$ 0	$ 0
Revolving credit facility interest rate	0.00%	0.00%

Long-Term Debt And Other Long_4

Long-Term Debt And Other Long-Term Liabilities (Other Long-Term Liabilities) (Details) - USD ($) $ in Thousands	Sep. 30, 2018	Jan. 01, 2018	Dec. 31, 2017	Sep. 30, 2017	Dec. 31, 2016
Debt Disclosure [Abstract]
Asset retirement obligation (ARO) liability	$ 62,727		$ 69,444	$ 75,485	$ 70,170
Workers' compensation	12,832		13,340
Capital lease obligations	12,355		15,224
Contract liability	10,605		0
Separation benefit plans	8,135		6,524
Deferred compensation plan	5,623		5,390
Gas balancing liability	3,283		3,283
Other liabilities	115,560		113,205
Current portion of other long-term liabilities	14,150	$ 15,750	13,002
Other long-term liabilities	$ 101,410	$ 109,940	$ 100,203

Long-Term Debt And Other Long_5

Long-Term Debt And Other Long-Term Liabilities (Capital Leases) (Details) - USD ($) $ in Thousands	Sep. 30, 2018	Dec. 31, 2017
Beginning October 1,
2,018	$ 6,195
2,019	6,195
2,020	5,322
Total future payments	17,712
Less payments related to:
Maintenance	4,601
Interest	756
Present value of future minimum payments	$ 12,355	$ 15,224

Long-Term Debt And Other Long_6

Long-Term Debt And Other Long-Term Liabilities (Narrative) (Details) - USD ($) $ in Thousands	May 02, 2018	Apr. 03, 2018	Sep. 30, 2018	Apr. 02, 2018	Mar. 31, 2018	Dec. 31, 2017
Debt Instrument [Line Items]
Variable Interest Entity, Date Involvement Began		Apr. 3, 2018
Aggregate principal amount			$ 650,000			$ 650,000
Interest percentage of senior subordinated notes			6.625%
Debt instrument maturity date			May 15, 2021
Original debt issuance fees			$ 14,700
Senior notes repurchase price in percentage			101.00%
Estimated principal payments in year 1			$ 14,100
Estimated principal payments in year 2			43,100
Estimated principal payments in year 3			659,800
Estimated principal payments in year 4			4,600
Estimated principal payments in year 5			$ 2,300
Number of compressors under capital lease agreement			20
Capital lease term			7 years
Capital Lease Obligations, Current			$ 4,000
Capital Lease Obligations, Noncurrent			$ 8,400
Discount rate capital leases			4.00%
Maintenance			$ 4,601
Interest			756
Capital leases, future minimum payments, average annual payment			$ 4,200
Capital lease fair market value percentage for purchase			10.00%
6.625% Senior Subordinated Notes Due 2021 [Member]
Debt Instrument [Line Items]
Aggregate principal amount			$ 650,000
Unit Credit Agreement [Member]
Debt Instrument [Line Items]
Credit facility maturity date			April 10, 2020
Credit facility maximum credit amount				$ 425,000	$ 875,000
Commitment fee percentage under credit facility			0.50%
Origination, agency and syndication and other related fees with the credit agreement			$ 1,000
Payable assessment term for LIBOR			90 days
Line of credit facility, amount outstanding			$ 0			178,000
LIBOR interest rate plus one percent			LIBOR plus 1.00% plus a margin
Unit Credit Agreement, Dividend Restrictions			the payment of dividends (other than stock dividends) during any fiscal year over 30% of our consolidated net income for the preceding fiscal year;
Unit Credit Agreement, Asset Restrictions			investments in Unrestricted Subsidiaries (as defined in the Unit credit agreement) over $200.0 million
Current ratio of credit facility			1 to 1
Leverage ratio of funded debt			4 to 1
Covenant Compliance			As of September 30, 2018, we were in compliance with the Unit credit agreement covenants.
Unit Credit Agreement [Member] | Minimum [Member]
Debt Instrument [Line Items]
LIBOR plus interest rate			2.00%
Unit Credit Agreement [Member] | Maximum [Member]
Debt Instrument [Line Items]
LIBOR plus interest rate			3.00%
Unit Credit Agreement [Member] | Line Of Credit Facility Lender Determined Amount [Member]
Debt Instrument [Line Items]
Credit facility current credit amount				425,000	475,000
Unit Credit Agreement [Member] | Line Of Credit Facility Commitment Amount [Member]
Debt Instrument [Line Items]
Credit facility current credit amount				425,000	$ 475,000
Unit Credit Agreement [Member] | Proved developed producing total value of our oil and gas properties [Member]
Debt Instrument [Line Items]
Percentage of collateral pledged			85.00%
Present worth discounted			8.00%
Superior Credit Agreement [Member]
Debt Instrument [Line Items]
Credit facility maximum credit amount			$ 250,000
Credit facility current credit amount			$ 200,000
Commitment fee percentage under credit facility			0.375%
Origination, agency and syndication and other related fees with the credit agreement			$ 1,700
Line of credit facility, amount outstanding			$ 0			$ 0
Covenant Compliance			As of September 30, 2018, Superior was in compliance with the Superior credit agreement covenants.
Superior Credit Agreement, Initiation Date			May 10, 2018
Superior Credit Agreement, Term			5 years
Superior Credit Agreement, Interest Rate Description			annual interest at a rate, at Superior’s option, equal to (a) LIBOR plus the applicable margin of 2.00% to 3.25% or (b) the alternate base rate (greater of (i) the federal funds rate plus 0.5%, (ii) the prime rate, and (iii) third day LIBOR plus 1.00%) plus the applicable margin of 1.00% to 2.25%.
Superior Credit Agreement [Member] | Minimum [Member]
Debt Instrument [Line Items]
Consolidated EBITDA to interest expense ratio			2.50 to 1.00
Superior Credit Agreement [Member] | Maximum [Member]
Debt Instrument [Line Items]
Funded debt to consolidated EBITDA ratio			4.00 to 1.00
Fourth Amendment to Credit Agreement [Member] | Unit Credit Agreement [Member]
Debt Instrument [Line Items]
Line of Credit Facility, Collateral	we granted a security interest in the limited liability membership interests and other equity interests we own in Superior (which as of this report is 50% of the aggregate outstanding equity interests of Superior
Origination, agency and syndication and other related fees with the credit agreement				$ 0

Asset Retirement Obligations (S

Asset Retirement Obligations (Schedule Of Asset Retirement Obligations) (Details) - USD ($) $ in Thousands		9 Months Ended
		Sep. 30, 2018	Sep. 30, 2017
Asset Retirement Obligation Disclosure [Abstract]
ARO liability, January 1:		$ 69,444	$ 70,170
Accretion of discount		1,829	2,112
Liability incurred		244	1,123
Liability settled		(3,907)	(1,350)
Liability sold		(105)	(1,563)
Revision of estimates	[1]	(4,778)	4,993
ARO liability, September 30:		62,727	75,485
Less current portion		1,451	2,947
Total long-term ARO		$ 61,276	$ 72,538
[1]	Plugging liability estimates were revised in both 2018 and 2017 for updates in the cost of services used to plug wells over the preceding year. We had various upward and downward adjustments.

Stock-Based Compensation (Sched

Stock-Based Compensation (Schedule of Restricted Stock Awards and Stock Options) (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 2017
Share-based Compensation Arrangement by Share-based Payment Award [Abstract]
Recognized stock compensation expense	$ 4.1	$ 3.2	$ 13.6	$ 9
Capitalized stock compensation cost for our oil and natural gas properties	0.6	0.5	1.6	1.3
Tax benefit on stock based compensation	$ 1	$ 1.2	$ 3.3	$ 3.4

Stock-Based Compensation (Sch_2

Stock-Based Compensation (Schedule of Fair Value of the Restricted Stock Awards Granted During the Periods) (Details) - Restricted Stock [Member] - USD ($) $ in Millions		9 Months Ended
		Sep. 30, 2018	Sep. 30, 2017
Time Vested [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Shares granted		888,810	524,903
Estimated fair value (in millions)	[1]	$ 17.1	$ 12.7
Time Vested [Member] | Employees [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Shares granted		844,498	475,799
Estimated fair value (in millions)	[1]	$ 16.2	$ 11.8
Percentage of shares granted expected to be distributed		95.00%	95.00%
Time Vested [Member] | Non-employee Directors [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Shares granted		44,312	49,104
Estimated fair value (in millions)	[1]	$ 0.9	$ 0.9
Percentage of shares granted expected to be distributed		100.00%	100.00%
Performance Shares [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Shares granted		362,070	173,373
Estimated fair value (in millions)	[1]	$ 7.3	$ 4.5
Performance Shares [Member] | Employees [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Shares granted		362,070	173,373
Estimated fair value (in millions)	[1]	$ 7.3	$ 4.5
Percentage of shares granted expected to be distributed		74.00%	91.00%
Performance Shares [Member] | Non-employee Directors [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Shares granted		0	0
Estimated fair value (in millions)	[1]	$ 0	$ 0
[1]	The performance shares represent 100% of the grant date fair value. (We recognize the grant date fair value minus estimated forfeitures.)

Stock-Based Compensation (Narra

Stock-Based Compensation (Narrative) (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 2017	May 06, 2015
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Unrecognized compensation cost related to unvested awards	$ 19		$ 19
Unrecognized compensation cost, expected to be capitalized	$ 2.4		$ 2.4
Weighted average years over which this cost will be recognized			1 year
Increase in stock compensation expense due to the restricted stock awards granted			$ 7.5
Stock Appreciation Rights (SARs) [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Shares granted	0	0	0	0
Restricted Stock [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Number of shares authorized					7,230,000
Incentive Stock Options [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Number of shares authorized					2,000,000
Employee Stock Option [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock options granted	0	0	0	0
Stock Performance Measures [Member] | Minimum [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Performance percentage criteria			0.00%
Stock Performance Measures [Member] | Maximum [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Performance percentage criteria			200.00%
Cash flow to total assets performance [Member] | Minimum [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Performance percentage criteria			0.00%
Cash flow to total assets performance [Member] | Maximum [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Performance percentage criteria			200.00%
Cash flow to total assets performance [Member] | Restricted Stock [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Performance percentage criteria			100.00%
Time Vested [Member] | Restricted Stock [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Award Vesting Period			3 years
Shares granted			888,810	524,903
Performance Shares [Member] | Restricted Stock [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Shares granted			362,070	173,373
Performance Shares [Member] | Cash flow to total assets performance [Member] | Restricted Stock [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Award Vesting Period			3 years
Cliff vest [Member] | Performance Shares [Member] | Stock Performance Measures [Member] | Restricted Stock [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Award Vesting Period			3 years
2018 [Member] | Restricted Stock [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Performance percentage criteria			49.00%
2017 [Member] | Restricted Stock [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Performance percentage criteria			92.00%
2016 [Member] | Restricted Stock [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Performance percentage criteria			170.00%

Derivatives (Schedule of Deriva

Derivatives (Schedule of Derivatives Outstanding) (Details)	9 Months Ended
	Sep. 30, 2018$ / UnitMMBTUbbl
Swap [Member] | Oct'18 [Member] | Natural Gas [Member] | IF - NYMEX (HH) [Member]
Derivative [Line Items]
Weighted average price	3.005
Hedged volume (MMBtu/day) | MMBTU	30,000
Swap [Member] | Oct'18 - Dec'18 [Member] | Crude Oil [Member] | WTI - NYMEX [Member]
Derivative [Line Items]
Weighted average price	53.52
Hedged volume (Bbl/day) | bbl	4,000
Swap [Member] | Nov'18 - Dec'18 [Member] | Natural Gas [Member] | IF - NYMEX (HH) [Member]
Derivative [Line Items]
Weighted average price	3.013
Hedged volume (MMBtu/day) | MMBTU	20,000
Swap [Member] | Jan'19 - Dec'19 [Member] | Natural Gas [Member] | IF - NYMEX (HH) [Member]
Derivative [Line Items]
Weighted average price	2.810
Hedged volume (MMBtu/day) | MMBTU	10,000
Price Risk Derivative [Member] | Oct'18 - Dec'18 [Member] | Crude Oil [Member] | LLS/WTI [Member]
Derivative [Line Items]
Weighted average price	7
Hedged volume (Bbl/day) | bbl	500
Basis swap [Member] | Oct'18 [Member] | Natural Gas [Member] | NGPL Texok [Member]
Derivative [Line Items]
Weighted average price	(0.190)
Hedged volume (MMBtu/day) | MMBTU	10,000
Basis swap [Member] | Oct'18 - Dec'18 [Member] | Natural Gas [Member] | NGPL Midcon [Member]
Derivative [Line Items]
Weighted average price	(0.568)
Hedged volume (MMBtu/day) | MMBTU	10,000
Basis swap [Member] | Oct'18 - Dec'18 [Member] | Natural Gas [Member] | PEPL [Member]
Derivative [Line Items]
Weighted average price	(0.678)
Hedged volume (MMBtu/day) | MMBTU	10,000
Basis swap [Member] | Nov'18 - Dec'18 [Member] | Natural Gas [Member] | IF - NYMEX (HH) [Member]
Derivative [Line Items]
Weighted average price	(0.208)
Hedged volume (MMBtu/day) | MMBTU	10,000
Basis swap [Member] | Jan'19 - Dec'19 [Member] | Natural Gas [Member] | NGPL Midcon [Member]
Derivative [Line Items]
Weighted average price	(0.625)
Hedged volume (MMBtu/day) | MMBTU	10,000
Basis swap [Member] | Jan'19 - Dec'19 [Member] | Natural Gas [Member] | NGPL Texok [Member]
Derivative [Line Items]
Weighted average price	(0.265)
Hedged volume (MMBtu/day) | MMBTU	30,000
Basis swap [Member] | Jan'19 - Dec'19 [Member] | Natural Gas [Member] | PEPL [Member]
Derivative [Line Items]
Weighted average price	(0.659)
Hedged volume (MMBtu/day) | MMBTU	20,000
Basis swap [Member] | Jan'20 - Dec'20 [Member] | Natural Gas [Member] | NGPL Texok [Member]
Derivative [Line Items]
Weighted average price	(0.275)
Hedged volume (MMBtu/day) | MMBTU	30,000
Three-way collar [Member] | Oct'18 - Dec'18 [Member] | Crude Oil [Member] | WTI - NYMEX [Member]
Derivative [Line Items]
Hedged volume (Bbl/day) | bbl	2,000
Cap Price	56.08
Subfloor price	37.50
Floor Price	47.50
Three-way collar [Member] | Oct'18 - Dec'18 [Member] | Natural Gas [Member] | IF - NYMEX (HH) [Member]
Derivative [Line Items]
Hedged volume (MMBtu/day) | MMBTU	20,000
Cap Price	3.51
Subfloor price	2.50
Floor Price	3
Three-way collar [Member] | Jan'19 - Dec'19 [Member] | Crude Oil [Member] | WTI - NYMEX [Member]
Derivative [Line Items]
Hedged volume (Bbl/day) | bbl	4,000
Cap Price	72.93
Subfloor price	51.25
Floor Price	61.25

Derivatives (Subsequent Schedul

Derivatives (Subsequent Schedule of Derivatives Outstanding) (Details) - Natural Gas [Member] - IF - NYMEX (HH) [Member]	1 Months Ended	9 Months Ended
	Nov. 06, 2018$ / UnitMMBTU	Sep. 30, 2018$ / UnitMMBTU
Swap [Member] | Jan'19 - Dec'19 [Member]
Derivative [Line Items]
Weighted average price		2.810
Hedged volume (MMBtu/day) | MMBTU		10,000
Subsequent Event [Member] | Swap [Member] | Jan'19 - Dec'19 [Member]
Derivative [Line Items]
Weighted average price	2.850
Hedged volume (MMBtu/day) | MMBTU	10,000
Subsequent Event [Member] | Collar [Member] | Jan'19 - Dec'19 [Member]
Derivative [Line Items]
Hedged volume (MMBtu/day) | MMBTU	20,000
Floor Price	2.63
Cap Price	3.03
Subsequent Event [Member] | Three-way collar [Member] | Jan'19 - Mar'19 [Member]
Derivative [Line Items]
Hedged volume (MMBtu/day) | MMBTU	10,000
Floor Price	3
Cap Price	4.35
Subfloor price	2.75

Derivatives (Fair Value of Deri

Derivatives (Fair Value of Derivative Instruments and Locations in Balance Sheets) (Details) - USD ($) $ in Thousands	Sep. 30, 2018	Dec. 31, 2017
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Current derivative asset	$ 0	$ 721
Non-current derivative asset	0	0
Total derivatives assets	0	721
Current derivative liability	(13,067)	(7,763)
Non-current derivative liability	(1,542)	0
Total derivative liabilities	$ (14,609)	$ (7,763)

Derivatives (Effect of Derivati

Derivatives (Effect of Derivative Instruments Recognized in Income Statements, Derivative Instruments) (Details) - USD ($) $ in Thousands	3 Months Ended				9 Months Ended
	Sep. 30, 2018		Sep. 30, 2017		Sep. 30, 2018		Sep. 30, 2017
Derivative Instruments, Gain (Loss) [Line Items]
Gain (loss) on derivatives	$ (4,385)		$ (2,614)		$ (25,608)		$ 21,019
Commodity Derivatives [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Gain (loss) on derivatives	(4,385)		(2,614)		(25,608)		21,019
Amount of gains (loss) settled during the period	(9,100)		800		(18,000)		(700)
Gain (loss) on derivatives [Member] | Commodity Derivatives [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Gain (loss) on derivatives	$ (4,385)	[1]	$ (2,614)	[1]	$ (25,608)	[2]	$ 21,019	[2]
[1]	Amounts settled during the 2018 and 2017 periods include net payments of $9.1 million and net proceeds of $0.8 million, respectively.
[2]	Amounts settled during the 2018 and 2017 periods include net payments of $18.0 million and $0.7 million, respectively.

Fair Value Measurements (Fair V

Fair Value Measurements (Fair Value of Available-for-sale Securities) (Details) - USD ($) $ in Thousands	9 Months Ended	12 Months Ended
	Sep. 30, 2018	Dec. 31, 2017
Schedule of Available-for-sale Securities [Line Items]
Cost	$ 830	$ 830
Gross unrealized gains	0	102
Gross unrealized losses	137	0
Available-for-sale Securities [Member]
Schedule of Available-for-sale Securities [Line Items]
Estimated fair value	693	932
Available-for-sale Securities [Member] | Level 1 [Member]
Schedule of Available-for-sale Securities [Line Items]
Estimated fair value	$ 693	$ 932

Fair Value Measurements (Recurr

Fair Value Measurements (Recurring Fair Value Measurements) (Details) - USD ($) $ in Thousands	Sep. 30, 2018	Dec. 31, 2017
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Derivative Asset	$ 0	$ 721
Derivative Liability	(14,609)	(7,763)
Financial assets (liabilities)	(13,916)	(6,110)
Level 1 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Financial assets (liabilities)	693	932
Level 2 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Financial assets (liabilities)	(7,090)	(6,836)
Level 3 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Financial assets (liabilities)	(7,519)	(206)
Effect of Netting [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Financial assets (liabilities)	0	0
Commodity Derivatives [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Derivative Asset	0	721
Derivative Liability	(14,609)	(7,763)
Total commodity derivatives	(14,609)	(7,042)
Commodity Derivatives [Member] | Level 1 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Gross Assets	0	0
Gross Liabilities	0	0
Total commodity derivatives	0	0
Commodity Derivatives [Member] | Level 2 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Gross Assets	1,282	2,137
Gross Liabilities	(8,372)	(8,973)
Total commodity derivatives	(7,090)	(6,836)
Commodity Derivatives [Member] | Level 3 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Gross Assets	88	3,344
Gross Liabilities	(7,607)	(3,550)
Total commodity derivatives	(7,519)	(206)
Commodity Derivatives [Member] | Effect of Netting [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Effect of netting on assets	(1,370)	(4,760)
Effect of netting on liabilities	1,370	4,760
Total commodity derivatives	0	0
Available-for-sale Securities [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Equity securities	693	932
Available-for-sale Securities [Member] | Level 1 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Equity securities	693	932
Available-for-sale Securities [Member] | Level 2 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Equity securities	0	0
Available-for-sale Securities [Member] | Level 3 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Equity securities	0	0
Available-for-sale Securities [Member] | Effect of Netting [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Equity securities	$ 0	$ 0

Fair Value Measurements (Reconc

Fair Value Measurements (Reconciliations Of Level 3 Fair Value Measurements) (Details) - Level 3 [Member] - USD ($) $ in Thousands		3 Months Ended		9 Months Ended
		Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 2017
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Beginning of period		$ (6,135)	$ 4,093	$ (206)	$ (7,122)
Included in earnings	[1]	(3,700)	(2,015)	(12,324)	9,102
Settlements		2,316	(592)	5,011	(494)
End of period		(7,519)	1,486	(7,519)	1,486
Total gains (losses) for the period included in earnings attributable to the change in unrealized gain relating to assets still held at end of period		$ (1,384)	$ (2,607)	$ (7,313)	$ 8,608
[1]	Commodity derivatives are reported in the Unaudited Condensed Consolidated Income Statements in gain (loss) on derivatives.

Fair Value Measurements (Schedu

Fair Value Measurements (Schedule Of Quantitative Information About Unobservable Inputs) (Details) - Level 3 [Member] - Three-way collar [Member] $ in Thousands	9 Months Ended
	Sep. 30, 2018USD ($)$ / Unit	[1]
Oil [Member]
Derivative fair value | $	$ (7,607)
Derivatives Valuation Technique(s)	Discounted cash flow
Unobservable Input	Forward commodity price curve
Oil [Member] | Minimum [Member]
Forward commodity price curve	0
Oil [Member] | Maximum [Member]
Forward commodity price curve	17.65
Natural Gas [Member]
Derivative fair value | $	$ 88
Derivatives Valuation Technique(s)	Discounted cash flow
Unobservable Input	Forward commodity price curve
Natural Gas [Member] | Minimum [Member]
Forward commodity price curve	0
Natural Gas [Member] | Maximum [Member]
Forward commodity price curve	0.12
[1]	The commodity contracts detailed in this category include non-exchange-traded crude oil and natural gas three-way collars that are valued based on NYMEX. The forward pricing range represents the low and high price expected to be paid or received within the settlement period.

Fair Value Measurements (Narrat

Fair Value Measurements (Narrative) (Details) - USD ($) $ in Thousands	Sep. 30, 2018	Dec. 31, 2017
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Collateral posted	$ 0
6.625% senior subordinated notes due 2021	643,900	$ 642,300
Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Estimated fair value of long-term debt	655,500	649,700
Unit Credit Agreement [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Line of credit facility, amount outstanding	$ 0	$ 178,000

Commitments and Contingencies (

Commitments and Contingencies (Narrative) (Details) - USD ($)	9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017
Long-term Purchase Commitment [Line Items]
Operating Leases, Future Minimum Payments Due, Next Twelve Months	$ 5,100,000
Operating Leases, Future Minimum Payments, Due in Two Years	2,100,000
Operating Leases, Future Minimum Payments, Due in Three Years	600,000
Operating Leases, Future Minimum Payments, Due in Four Years	100,000
Operating Leases, Rent Expense, Net	$ 7,200,000	$ 6,400,000
Number of compressors under capital lease agreement	20
Capital lease term	7 years
Capital Leases, Future Minimum Payments Due, Next Twelve Months	$ 6,195,000
Capital Leases, Future Minimum Payments Due in Two Years	6,195,000
Capital Leases, Future Minimum Payments Due in Three Years	5,322,000
Maintenance	4,601,000
Interest	756,000
Capital leases, future minimum payments, average annual payment	$ 4,200,000
Capital lease fair market value percentage for purchase	10.00%
Percentage of repurchase of limited units outstanding	20.00%
Repurchase Of Limited Units Outstanding Amount	$ 1,700	$ 2,900
Drilling Equipment [Member]
Long-term Purchase Commitment [Line Items]
Other Commitment, Due in Next Twelve Months	$ 10,064,000
Capital Addition Purchase Commitments [Member] | Oil and Natural Gas [Member]
Long-term Purchase Commitment [Line Items]
Long-term Purchase Commitment, Description	as part of the Superior transaction, we entered into a contractual obligation that commits us to spend $150.0 million to drill wells in the Granite Wash/Buffalo Wallow area over three years starting January 1, 2019. This amount is already included in our drilling plan. For each dollar of the $150.0 million that we do not spend (over the three year period), we would forgo receiving $0.58 of future distributions from our 50% ownership interest in our consolidated mid-stream subsidiary. If we elected not to drill or spend any money in the designated area over the three year period, the maximum amount we could forgo from distributions would be $87.0 million.
Long-term Purchase Commitment, Amount	$ 150,000,000
Long-term Purchase Commitment, Period	3 years

Variable Interest Entity Arra_3

Variable Interest Entity Arrangements (Schedule of Assets and Liabilities) (Details) - USD ($) $ in Thousands	Sep. 30, 2018		Jan. 01, 2018	Dec. 31, 2017	Sep. 30, 2017	Dec. 31, 2016
Current assets:
Cash and cash equivalents	$ 91,557			$ 701	$ 822	$ 893
Accounts receivable, net of allowance for doubtful accounts	122,123			111,512
Prepaid expenses and other	9,419			6,233
Total current assets	223,604			119,672
Property and equipment:
Gas gathering and processing equipment	751,715			726,236
Transportation equipment	29,103			29,631
Property, plant, and equipment, gross	8,830,810			8,534,192
Less accumulated depreciation, depletion, amortization, and impairment	6,325,160			6,151,450
Net property and equipment	2,505,650			2,382,742
Other assets	28,703		$ 27,028	16,230
Total assets	2,820,765	[1]		2,581,452
Current liabilities:
Accounts payable	143,552			112,648
Accrued liabilities	67,743			48,523
Current portion of other long-term liabilities	14,150		15,750	13,002
Total current liabilities	239,563			181,936
Long-term debt less debt issuance costs	643,921			820,276
Other long-term liabilities	101,410		$ 109,940	$ 100,203
VIE [Member]
Current assets:
Cash and cash equivalents	9,039
Accounts receivable, net of allowance for doubtful accounts	29,991
Prepaid expenses and other	2,756
Total current assets	41,786
Property and equipment:
Gas gathering and processing equipment	751,715
Transportation equipment	3,064
Property, plant, and equipment, gross	754,779
Less accumulated depreciation, depletion, amortization, and impairment	353,476
Net property and equipment	401,303
Other assets	15,411
Total assets	458,500
Current liabilities:
Accounts payable	28,183
Accrued liabilities	3,574
Current portion of other long-term liabilities	6,836
Total current liabilities	38,593
Long-term debt less debt issuance costs	0
Other long-term liabilities	16,126
Total liabilities	$ 54,719
[1]	Unit Corporation's consolidated total assets as of September 30, 2018 include total current and long-term assets of its variable interest entity (VIE) (Superior Pipeline Company, L.L.C.) of $41.8 million and $416.7 million, respectively, which can only be used to settle obligations of the VIE. Unit Corporation's consolidated total liabilities as of September 30, 2018 include total current and long-term liabilities of the VIE of $38.6 million and $16.1 million, respectively, for which the creditors of the VIE have no recourse to Unit Corporation. See Note 13 – Variable Interest Entity Arrangements.

Variable Interest Entity Arra_4

Variable Interest Entity Arrangements (Details) - USD ($)	Apr. 03, 2018	Sep. 30, 2018
Variable Interest Entity [Line Items]
Date Involvement Began	Apr. 3, 2018
Superior Pipeline Company, L.L.C. [Member]
Variable Interest Entity [Line Items]
Date Involvement Began		Apr. 3, 2018
Methodology for Determining Whether Entity is Primary Beneficiary		The two variable interests applicable to Unit include the 50% equity investment in Superior and the MSA. The MSA houses the power to direct the activities that most significantly impact Superior's operating performance. The MSA is a separate variable interest. Unit through the MSA has the power to direct Superior’s most significant activities; reciprocally the equity investors lack the power to direct the activities that most significantly impact the entity’s economic performance. Because of this, Unit is considered the primary beneficiary.
Lack of Recourse		Superior's creditors have no recourse to our general credit.
SP Investor Holdings, LLC [Member] | Superior Pipeline Company, L.L.C. [Member]
Variable Interest Entity [Line Items]
Ownership Percentage		50.00%
SPC Midstream Operating, L.L.C. [Member] | Superior Pipeline Company, L.L.C. [Member]
Variable Interest Entity [Line Items]
Monthly service fee		$ 250,000

Equity (Schedule of Accumulated

Equity (Schedule of Accumulated Other Comprehensive Income) (Details) - USD ($) $ in Thousands	3 Months Ended			9 Months Ended
	Sep. 30, 2018		Sep. 30, 2017	Sep. 30, 2018		Sep. 30, 2017
Schedule of Accumulated Other Comprehensive Income (Loss) [Abstract]
Unrealized appreciation (loss) on securities, before tax	$ (51)		$ 53	$ (239)		$ 85
Tax benefit (expense)	13	[1]	(20)	60	[2]	(32)
Unrealized appreciation (loss) on securities, net of tax	$ (38)		$ 33	$ (179)		$ 53
[1]	Due to the implementation of ASU 2018-02, the tax rate changed from 37.75% to 24.5%.
[2]	Due to the implementation of ASU 2018-02, the tax rate changed from 37.75% to 24.5%.

Equity (Reclassification out of

Equity (Reclassification out of Accumulated Other Comprehensive Income) (Details) - USD ($) $ in Thousands	3 Months Ended			9 Months Ended
	Sep. 30, 2018		Sep. 30, 2017	Sep. 30, 2018		Sep. 30, 2017	Jan. 01, 2018		Dec. 31, 2016
New Accounting Pronouncement, Early Adoption [Line Items]
Beginning Balance	$ (65)		$ 20	$ 63		$ 0
Accumulated other comprehensive income (loss)	(65)		20	63		0	$ 63		$ 0
Unrealized appreciation (loss) before reclassifications	(38)	[1]	33	(179)	[2]	53
Amounts reclassified from accumulated other comprehensive income	0		0	0		0
Net current-period other comprehensive income (loss)	(38)		33	(179)		53
Ending Balance	$ (103)		$ 53	$ (103)		$ 53
ASU 2018-02 effect
New Accounting Pronouncement, Early Adoption [Line Items]
Adjustment due to ASU 2018-02							13	[2]	$ 0
ASU 2018-02 end balance
New Accounting Pronouncement, Early Adoption [Line Items]
Accumulated other comprehensive income (loss)							$ 76
[1]	Due to the implementation of ASU 2018-02, the tax rate changed from 37.75% to 24.5%.
[2]	Due to the implementation of ASU 2018-02, the tax rate changed from 37.75% to 24.5%.

Equity (Narrative) (Details)

Equity (Narrative) (Details) - USD ($) $ / shares in Units, $ in Thousands	9 Months Ended		13 Months Ended
	Sep. 30, 2018	Sep. 30, 2017	May 02, 2018	Dec. 31, 2017	Apr. 04, 2017
Class of Stock [Line Items]
Common stock, par value	$ 0.20			$ 0.20
Common stock, shares issued	54,063,705			52,880,134
Proceeds from issuance of common stock, net of issuance costs	$ 0	$ 18,623
Terminated May 2, 2018 [Member] | At-the-Market Common Stock Program [Member]
Class of Stock [Line Items]
Common stock, par value					$ 0.20
Aggregate Offering Price					$ 100,000
Proceeds from issuance of common stock, net of issuance costs			$ 18,623
Commission of the gross sales price by share paid percentage					2.00%
ATM Distribution Agreement [Member] | Terminated May 2, 2018 [Member] | At-the-Market Common Stock Program [Member]
Class of Stock [Line Items]
Common stock, shares issued			787,547

Industry Segment Information (I

Industry Segment Information (Industry Segment Information) (Details) - USD ($) $ in Thousands	3 Months Ended			9 Months Ended
	Sep. 30, 2018		Sep. 30, 2017	Sep. 30, 2018		Sep. 30, 2017
Revenues:
Oil and natural gas	$ 111,623		$ 85,470	$ 317,040		$ 256,241
Contract drilling	50,612		51,619	143,527		128,059
Gas gathering and processing	57,823		51,399	167,926		150,493
Total revenues	220,058		188,488	628,493		534,793
Operating costs:
Oil and natural gas	32,139		33,911	100,519		95,873
Contract drilling	32,032		34,747	95,593		91,213
Gas gathering and processing	43,134		38,116	124,441		111,862
Total operating costs	107,305		106,774	320,553		298,948
Depreciation, depletion, and amortization	63,537		54,533	178,976		151,545
Total expenses	170,842		161,307	499,529		450,493
General and administrative	9,278		9,235	28,752		26,902
(Gain) loss on disposition of assets	(253)		(81)	(575)		(1,153)
Income (loss) from operations	40,191		18,027	100,787		58,551
Gain (loss) on derivatives	(4,385)		(2,614)	(25,608)		21,019
Interest, net	(7,945)		(9,944)	(25,678)		(28,807)
Other	6		5	17		14
Income (loss) before income taxes	27,867		5,474	49,518		50,777
Oil and Natural Gas [Member]
Revenues:
Oil and natural gas	111,623	[1]	85,470	317,040	[2]	256,241
Contract drilling	0	[1]	0	0	[2]	0
Gas gathering and processing	0	[1]	0	0	[2]	0
Total revenues	111,623	[1]	85,470	317,040	[2]	256,241
Operating costs:
Oil and natural gas	33,400		35,082	104,234		99,349
Contract drilling	0		0	0		0
Gas gathering and processing	0		0	0		0
Total operating costs	33,400		35,082	104,234		99,349
Depreciation, depletion, and amortization	35,460		26,460	97,797		71,544
Total expenses	68,860		61,542	202,031		170,893
General and administrative	0		0	0		0
(Gain) loss on disposition of assets	(7)		1	(136)		(176)
Income (loss) from operations	42,770		23,927	115,145		85,524
Gain (loss) on derivatives	0		0	0		0
Interest, net	0		0	0		0
Other	0		0	0		0
Income (loss) before income taxes	42,770		23,927	115,145		85,524
Drilling [Member]
Revenues:
Oil and natural gas	0	[1]	0	0	[2]	0
Contract drilling	58,012	[1]	55,588	161,489	[2]	137,617
Gas gathering and processing	0	[1]	0	0	[2]	0
Total revenues	58,012	[1]	55,588	161,489	[2]	137,617
Operating costs:
Oil and natural gas	0		0	0		0
Contract drilling	38,246		38,115	111,121		99,794
Gas gathering and processing	0		0	0		0
Total operating costs	38,246		38,115	111,121		99,794
Depreciation, depletion, and amortization	14,889		15,280	41,927		41,896
Total expenses	53,135		53,395	153,048		141,690
General and administrative	0		0	0		0
(Gain) loss on disposition of assets	(230)		(68)	(314)		(106)
Income (loss) from operations	5,107		2,261	8,755		(3,967)
Gain (loss) on derivatives	0		0	0		0
Interest, net	0		0	0		0
Other	0		0	0		0
Income (loss) before income taxes	5,107		2,261	8,755		(3,967)
Mid-Stream [Member]
Revenues:
Oil and natural gas	0	[1]	0	0	[2]	0
Contract drilling	0	[1]	0	0	[2]	0
Gas gathering and processing	82,882	[1]	69,057	232,938	[2]	198,632
Total revenues	82,882	[1]	69,057	232,938	[2]	198,632
Operating costs:
Oil and natural gas	0		0	0		0
Contract drilling	0		0	0		0
Gas gathering and processing	66,932		54,602	185,738		156,525
Total operating costs	66,932		54,602	185,738		156,525
Depreciation, depletion, and amortization	11,265		10,880	33,493		32,547
Total expenses	78,197		65,482	219,231		189,072
General and administrative	0		0	0		0
(Gain) loss on disposition of assets	(16)		(14)	(95)		(58)
Income (loss) from operations	4,701		3,589	13,802		9,618
Gain (loss) on derivatives	0		0	0		0
Interest, net	(381)		0	(834)		0
Other	0		0	0		0
Income (loss) before income taxes	4,320		3,589	12,968		9,618
Other Segments [Member]
Revenues:
Oil and natural gas	0	[1]	0	0	[2]	0
Contract drilling	0	[1]	0	0	[2]	0
Gas gathering and processing	0	[1]	0	0	[2]	0
Total revenues	0	[1]	0	0	[2]	0
Operating costs:
Oil and natural gas	0		0	0		0
Contract drilling	0		0	0		0
Gas gathering and processing	3,808		0	7,384		0
Total operating costs	3,808		0	7,384		0
Depreciation, depletion, and amortization	1,923		1,913	5,759		5,558
Total expenses	5,731		1,913	13,143		5,558
General and administrative	9,278		9,235	28,752		26,902
(Gain) loss on disposition of assets	0		0	(30)		(813)
Income (loss) from operations	(15,009)		(11,148)	(41,865)		(31,647)
Gain (loss) on derivatives	(4,385)		(2,614)	(25,608)		21,019
Interest, net	(7,564)		(9,944)	(24,844)		(28,807)
Other	3,814		5	7,401		14
Income (loss) before income taxes	(23,144)		(23,701)	(84,916)		(39,421)
Eliminations [Member]
Revenues:
Oil and natural gas	0		0	0		0
Contract drilling	(7,400)		(3,969)	(17,962)		(9,558)
Gas gathering and processing	(25,059)		(17,658)	(65,012)		(48,139)
Total revenues	(32,459)		(21,627)	(82,974)		(57,697)
Operating costs:
Oil and natural gas	(1,261)		(1,171)	(3,715)		(3,476)
Contract drilling	(6,214)		(3,368)	(15,528)		(8,581)
Gas gathering and processing	(27,606)		(16,486)	(68,681)		(44,663)
Total operating costs	(35,081)		(21,025)	(87,924)		(56,720)
Depreciation, depletion, and amortization	0		0	0		0
Total expenses	(35,081)		(21,025)	(87,924)		(56,720)
General and administrative	0		0	0		0
(Gain) loss on disposition of assets	0		0	0		0
Income (loss) from operations	2,622		(602)	4,950		(977)
Gain (loss) on derivatives	0		0	0		0
Interest, net	0		0	0		0
Other	(3,808)		0	(7,384)		0
Income (loss) before income taxes	$ (1,186)		$ (602)	$ (2,434)		$ (977)
[1]	The revenues for oil and natural gas occur at a point in time. The revenues for contract drilling and gas gathering and processing occur over time.
[2]	The revenues for oil and natural gas occur at a point in time. The revenues for contract drilling and gas gathering and processing occur over time.

Supplemental Condensed Consol_3

Supplemental Condensed Consolidated Financial Information (Condensed Consolidating Balance Sheets) (Details) - USD ($) $ in Thousands	Sep. 30, 2018		Jun. 30, 2018	Jan. 01, 2018	Dec. 31, 2017	Sep. 30, 2017	Jun. 30, 2017	Dec. 31, 2016
Current assets:
Cash and cash equivalents	$ 91,557				$ 701	$ 822		$ 893
Accounts receivable, net of allowance for doubtful accounts	122,123				111,512
Materials and supplies	505				505
Current derivative asset	0				721
Prepaid expenses and other	9,419				6,233
Total current assets	223,604				119,672
Oil and natural gas properties on the full cost method:
Proved properties	5,901,661				5,712,813
Unproved properties not being amortized	332,886				296,764
Drilling equipment	1,632,540				1,593,611
Gas gathering and processing equipment	751,715				726,236
Saltwater disposal systems	67,074				62,618
Corporate land and building	59,081				59,080
Transportation equipment	29,103				29,631
Other	56,750				53,439
Property, plant, and equipment, gross	8,830,810				8,534,192
Less accumulated depreciation, depletion, amortization, and impairment	6,325,160				6,151,450
Net property and equipment	2,505,650				2,382,742
Intercompany receivable	0				0
Goodwill	62,808				62,808
Investments	1,500				1,500
Other assets	27,203				14,730
Total assets	2,820,765	[1]			2,581,452
Current liabilities:
Accounts payable	143,552				112,648
Accrued liabilities	67,743				48,523
Income taxes payable	1,051				0
Current derivative liability	13,067				7,763
Current portion of other long-term liabilities	14,150			$ 15,750	13,002
Total current liabilities	239,563				181,936
Intercompany debt	0				0
Long-term debt					178,000
Bonds payable less debt issuance costs	643,921				642,276
Non-current derivative liability	1,542				0
Other long-term liabilities	101,410			109,940	100,203
Deferred income taxes	164,964			133,064	133,477
Shareholders' equity:
Preferred stock, $1.00 par value, 5,000,000 shares authorized, none issued	0				0
Common stock, $.20 par value, 175,000,000 shares authorized	10,414				10,280
Capital in excess of par value	626,746				535,815
Contributions from Unit	0				0
Accumulated other comprehensive income (loss)	(103)		$ (65)	63	63	53	$ 20	0
Retained earnings	830,680			$ 798,128	799,402
Total shareholders’ equity attributable to Unit Corporation	1,467,737				1,345,560
Non-controlling interests in consolidated subsidiaries	201,628				0
Total shareholders' equity	1,669,365				1,345,560	1,251,905		1,194,070
Total liabilities and shareholders' equity	2,820,765	[1]			2,581,452
Consolidating Adjustments [Member]
Current assets:
Cash and cash equivalents	0				0	0		0
Accounts receivable, net of allowance for doubtful accounts	0				0
Materials and supplies	0				0
Current derivative asset	0				0
Prepaid expenses and other	0				0
Total current assets	0				0
Oil and natural gas properties on the full cost method:
Proved properties	0				0
Unproved properties not being amortized	0				0
Drilling equipment	0				0
Gas gathering and processing equipment	0				0
Saltwater disposal systems	0				0
Corporate land and building	0				0
Transportation equipment	0				0
Other	0				0
Property, plant, and equipment, gross	0				0
Less accumulated depreciation, depletion, amortization, and impairment	0				0
Net property and equipment	0				0
Intercompany receivable	(907,907)				(1,155,725)
Goodwill	0				0
Investments	(1,248,309)				(1,044,709)
Other assets	0				0
Total assets	(2,156,216)				(2,200,434)
Current liabilities:
Accounts payable	0				0
Accrued liabilities	0				0
Income taxes payable	0
Current derivative liability	0				0
Current portion of other long-term liabilities	0				0
Total current liabilities	0				0
Intercompany debt	(907,382)				(1,155,725)
Long-term debt					0
Bonds payable less debt issuance costs	0				0
Non-current derivative liability	0
Other long-term liabilities	0				0
Deferred income taxes	0				0
Shareholders' equity:
Preferred stock, $1.00 par value, 5,000,000 shares authorized, none issued	0				0
Common stock, $.20 par value, 175,000,000 shares authorized	0				0
Capital in excess of par value	(242,963)				(61,470)
Contributions from Unit	(525)				0
Accumulated other comprehensive income (loss)	0				0
Retained earnings	(1,005,346)				(983,239)
Total shareholders’ equity attributable to Unit Corporation	(1,248,834)				(1,044,709)
Non-controlling interests in consolidated subsidiaries	0				0
Total shareholders' equity	(1,248,834)				(1,044,709)
Total liabilities and shareholders' equity	(2,156,216)				(2,200,434)
Parent [Member]
Current assets:
Cash and cash equivalents	82,267				510	504		517
Accounts receivable, net of allowance for doubtful accounts	1,374				154
Materials and supplies	0				0
Current derivative asset	0				721
Prepaid expenses and other	3,125				2,986
Total current assets	86,766				4,371
Oil and natural gas properties on the full cost method:
Proved properties	0				0
Unproved properties not being amortized	0				0
Drilling equipment	0				0
Gas gathering and processing equipment	0				0
Saltwater disposal systems	0				0
Corporate land and building	0				0
Transportation equipment	9,273				9,270
Other	28,506				28,039
Property, plant, and equipment, gross	37,779				37,309
Less accumulated depreciation, depletion, amortization, and impairment	25,922				21,268
Net property and equipment	11,857				16,041
Intercompany receivable	907,907				1,155,725
Goodwill	0				0
Investments	1,248,309				1,044,709
Other assets	5,605				5,373
Total assets	2,260,444				2,226,219
Current liabilities:
Accounts payable	28,116				13,124
Accrued liabilities	36,444				26,165
Income taxes payable	1,051
Current derivative liability	13,067				7,763
Current portion of other long-term liabilities	966				657
Total current liabilities	79,644				47,709
Intercompany debt	0				0
Long-term debt					178,000
Bonds payable less debt issuance costs	643,921				642,276
Non-current derivative liability	1,542
Other long-term liabilities	12,790				11,257
Deferred income taxes	54,707				1,480
Shareholders' equity:
Preferred stock, $1.00 par value, 5,000,000 shares authorized, none issued	0				0
Common stock, $.20 par value, 175,000,000 shares authorized	10,414				10,280
Capital in excess of par value	626,746				535,815
Contributions from Unit	0				0
Accumulated other comprehensive income (loss)	0				0
Retained earnings	830,680				799,402
Total shareholders’ equity attributable to Unit Corporation	1,467,840				1,345,497
Non-controlling interests in consolidated subsidiaries	0				0
Total shareholders' equity	1,467,840				1,345,497
Total liabilities and shareholders' equity	2,260,444				2,226,219
Combined Guarantor Subsidiaries [Member]
Current assets:
Cash and cash equivalents	251				191	318		376
Accounts receivable, net of allowance for doubtful accounts	92,078				83,442
Materials and supplies	505				505
Current derivative asset	0				0
Prepaid expenses and other	3,538				2,370
Total current assets	96,372				86,508
Oil and natural gas properties on the full cost method:
Proved properties	5,901,661				5,712,813
Unproved properties not being amortized	332,886				296,764
Drilling equipment	1,632,540				1,593,611
Gas gathering and processing equipment	0				0
Saltwater disposal systems	67,074				62,618
Corporate land and building	59,081				59,080
Transportation equipment	16,766				17,423
Other	28,244				25,400
Property, plant, and equipment, gross	8,038,252				7,767,709
Less accumulated depreciation, depletion, amortization, and impairment	5,945,762				5,807,757
Net property and equipment	2,092,490				1,959,952
Intercompany receivable	0				0
Goodwill	62,808				62,808
Investments	1,500				1,500
Other assets	6,186				6,328
Total assets	2,259,356				2,117,096
Current liabilities:
Accounts payable	90,543				81,334
Accrued liabilities	26,583				19,134
Income taxes payable	0
Current derivative liability	0				0
Current portion of other long-term liabilities	6,348				8,501
Total current liabilities	123,474				108,969
Intercompany debt	906,296				870,582
Long-term debt					0
Bonds payable less debt issuance costs	0				0
Non-current derivative liability	0
Other long-term liabilities	72,494				77,566
Deferred income taxes	110,257				85,443
Shareholders' equity:
Preferred stock, $1.00 par value, 5,000,000 shares authorized, none issued	0				0
Common stock, $.20 par value, 175,000,000 shares authorized	0				0
Capital in excess of par value	45,921				45,921
Contributions from Unit	0				0
Accumulated other comprehensive income (loss)	(103)				63
Retained earnings	1,001,017				928,552
Total shareholders’ equity attributable to Unit Corporation	1,046,835				974,536
Non-controlling interests in consolidated subsidiaries	0				0
Total shareholders' equity	1,046,835				974,536
Total liabilities and shareholders' equity	2,259,356				2,117,096
Combined Non-Guarantor Subsidiaries [Member]
Current assets:
Cash and cash equivalents	9,039				0	$ 0		$ 0
Accounts receivable, net of allowance for doubtful accounts	28,671				27,916
Materials and supplies	0				0
Current derivative asset	0				0
Prepaid expenses and other	2,756				877
Total current assets	40,466				28,793
Oil and natural gas properties on the full cost method:
Proved properties	0				0
Unproved properties not being amortized	0				0
Drilling equipment	0				0
Gas gathering and processing equipment	751,715				726,236
Saltwater disposal systems	0				0
Corporate land and building	0				0
Transportation equipment	3,064				2,938
Other	0				0
Property, plant, and equipment, gross	754,779				729,174
Less accumulated depreciation, depletion, amortization, and impairment	353,476				322,425
Net property and equipment	401,303				406,749
Intercompany receivable	0				0
Goodwill	0				0
Investments	0				0
Other assets	15,412				3,029
Total assets	457,181				438,571
Current liabilities:
Accounts payable	24,893				18,190
Accrued liabilities	4,716				3,224
Income taxes payable	0
Current derivative liability	0				0
Current portion of other long-term liabilities	6,836				3,844
Total current liabilities	36,445				25,258
Intercompany debt	1,086				285,143
Long-term debt					0
Bonds payable less debt issuance costs	0				0
Non-current derivative liability	0
Other long-term liabilities	16,126				11,380
Deferred income taxes	0				46,554
Shareholders' equity:
Preferred stock, $1.00 par value, 5,000,000 shares authorized, none issued	0				0
Common stock, $.20 par value, 175,000,000 shares authorized	0				0
Capital in excess of par value	197,042				15,549
Contributions from Unit	525				0
Accumulated other comprehensive income (loss)	0				0
Retained earnings	4,329				54,687
Total shareholders’ equity attributable to Unit Corporation	201,896				70,236
Non-controlling interests in consolidated subsidiaries	201,628				0
Total shareholders' equity	403,524				70,236
Total liabilities and shareholders' equity	$ 457,181				$ 438,571
[1]	Unit Corporation's consolidated total assets as of September 30, 2018 include total current and long-term assets of its variable interest entity (VIE) (Superior Pipeline Company, L.L.C.) of $41.8 million and $416.7 million, respectively, which can only be used to settle obligations of the VIE. Unit Corporation's consolidated total liabilities as of September 30, 2018 include total current and long-term liabilities of the VIE of $38.6 million and $16.1 million, respectively, for which the creditors of the VIE have no recourse to Unit Corporation. See Note 13 – Variable Interest Entity Arrangements.

Supplemental Condensed Consol_4

Supplemental Condensed Consolidated Financial Information Supplemental Condensed Consolidated Financial Information (Condensed Consolidating Balance Sheets) (Parenthetical) (Details) - USD ($) $ in Thousands	Sep. 30, 2018	Dec. 31, 2017
Condensed Financial Statements, Captions [Line Items]
Accounts receivable, allowance for doubtful accounts	$ 2,450	$ 2,450
Common stock, shares issued	54,063,705	52,880,134
Consolidating Adjustments [Member]
Condensed Financial Statements, Captions [Line Items]
Accounts receivable, allowance for doubtful accounts	$ 0	$ 0
Common stock, shares issued	0	0
Parent [Member]
Condensed Financial Statements, Captions [Line Items]
Accounts receivable, allowance for doubtful accounts	$ 0	$ 0
Common stock, shares issued	54,063,705	52,880,134
Combined Guarantor Subsidiaries [Member]
Condensed Financial Statements, Captions [Line Items]
Accounts receivable, allowance for doubtful accounts	$ 1,245	$ 1,245
Common stock, shares issued	0	0
Combined Non-Guarantor Subsidiaries [Member]
Condensed Financial Statements, Captions [Line Items]
Accounts receivable, allowance for doubtful accounts	$ 1,205	$ 1,205
Common stock, shares issued	0	0

Supplemental Condensed Consol_5

Supplemental Condensed Consolidated Financial Information (Condensed Consolidating Statements of Income) (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 2017
Condensed Financial Statements, Captions [Line Items]
Revenues	$ 220,058	$ 188,488	$ 628,493	$ 534,793
Expenses:
Operating costs	107,305	106,774	320,553	298,948
Depreciation, depletion, and amortization	63,537	54,533	178,976	151,545
General and administrative	9,278	9,235	28,752	26,902
Gain on disposition of assets	(253)	(81)	(575)	(1,153)
Total operating costs	179,867	170,461	527,706	476,242
Income (loss) from operations	40,191	18,027	100,787	58,551
Interest, net	(7,945)	(9,944)	(25,678)	(28,807)
Gain (loss) on derivatives	(4,385)	(2,614)	(25,608)	21,019
Other, net	6	5	17	14
Income (loss) before income taxes	27,867	5,474	49,518	50,777
Income tax expense (benefit)	6,744	1,769	12,380	22,084
Equity in net earnings from investment in subsidiaries, net of taxes	0	0	0	0
Net income	21,123	3,705	37,138	28,693
Less: net income attributable to non-controlling interest	2,224	0	4,586	0
Net income attributable to Unit Corporation	18,899	3,705	32,552	28,693
Consolidating Adjustments [Member]
Condensed Financial Statements, Captions [Line Items]
Revenues	(32,459)	(21,627)	(82,974)	(57,697)
Expenses:
Operating costs	(31,273)	(21,026)	(80,540)	(56,720)
Depreciation, depletion, and amortization	0	0	0	0
General and administrative	0	0	0	0
Gain on disposition of assets	0	0	0	0
Total operating costs	(31,273)	(21,026)	(80,540)	(56,720)
Income (loss) from operations	(1,186)	(601)	(2,434)	(977)
Interest, net	0	0	0	0
Gain (loss) on derivatives	0	0	0	0
Other, net	0	0	0	0
Income (loss) before income taxes	(1,186)	(601)	(2,434)	(977)
Income tax expense (benefit)	0	0	0	0
Equity in net earnings from investment in subsidiaries, net of taxes	(29,077)	(12,377)	(74,360)	(35,786)
Net income	(30,263)	(12,978)	(76,794)	(36,763)
Less: net income attributable to non-controlling interest	0	0	0	0
Net income attributable to Unit Corporation	(30,263)	(12,978)	(76,794)	(36,763)
Parent [Member]
Condensed Financial Statements, Captions [Line Items]
Revenues	0	0	0	0
Expenses:
Operating costs	0	0	0	0
Depreciation, depletion, and amortization	1,923	1,913	5,759	5,558
General and administrative	0	0	0	0
Gain on disposition of assets	0	0	(30)	(813)
Total operating costs	1,923	1,913	5,729	4,745
Income (loss) from operations	(1,923)	(1,913)	(5,729)	(4,745)
Interest, net	(7,564)	(9,776)	(24,844)	(28,276)
Gain (loss) on derivatives	(4,385)	(2,614)	(25,608)	21,019
Other, net	6	5	17	14
Income (loss) before income taxes	(13,866)	(14,298)	(56,164)	(11,988)
Income tax expense (benefit)	(3,688)	(5,626)	(14,356)	(4,895)
Equity in net earnings from investment in subsidiaries, net of taxes	29,077	12,377	74,360	35,786
Net income	18,899	3,705	32,552	28,693
Less: net income attributable to non-controlling interest	0	0	0	0
Net income attributable to Unit Corporation	18,899	3,705	32,552	28,693
Combined Guarantor Subsidiaries [Member]
Condensed Financial Statements, Captions [Line Items]
Revenues	169,635	141,058	478,529	393,858
Expenses:
Operating costs	71,646	73,197	215,355	199,143
Depreciation, depletion, and amortization	50,349	41,740	139,724	113,440
General and administrative	9,252	7,083	26,136	20,880
Gain on disposition of assets	(237)	(67)	(450)	(282)
Total operating costs	131,010	121,953	380,765	333,181
Income (loss) from operations	38,625	19,105	97,764	60,677
Interest, net	0	0	0	0
Gain (loss) on derivatives	0	0	0	0
Other, net	(1)	0	0	0
Income (loss) before income taxes	38,624	19,105	97,764	60,677
Income tax expense (benefit)	9,839	7,003	25,299	25,357
Equity in net earnings from investment in subsidiaries, net of taxes	0	0	0	0
Net income	28,785	12,102	72,465	35,320
Less: net income attributable to non-controlling interest	0	0	0	0
Net income attributable to Unit Corporation	28,785	12,102	72,465	35,320
Combined Non-Guarantor Subsidiaries [Member]
Condensed Financial Statements, Captions [Line Items]
Revenues	82,882	69,057	232,938	198,632
Expenses:
Operating costs	66,932	54,603	185,738	156,525
Depreciation, depletion, and amortization	11,265	10,880	33,493	32,547
General and administrative	26	2,152	2,616	6,022
Gain on disposition of assets	(16)	(14)	(95)	(58)
Total operating costs	78,207	67,621	221,752	195,036
Income (loss) from operations	4,675	1,436	11,186	3,596
Interest, net	(381)	(168)	(834)	(531)
Gain (loss) on derivatives	0	0	0	0
Other, net	1	0	0	0
Income (loss) before income taxes	4,295	1,268	10,352	3,065
Income tax expense (benefit)	593	392	1,437	1,622
Equity in net earnings from investment in subsidiaries, net of taxes	0	0	0	0
Net income	3,702	876	8,915	1,443
Less: net income attributable to non-controlling interest	2,224	0	4,586	0
Net income attributable to Unit Corporation	$ 1,478	$ 876	$ 4,329	$ 1,443

Supplemental Condensed Consol_6

Supplemental Condensed Consolidated Financial Information (Condensed Consolidating Statements of Comprehensive Income) (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 2017
Condensed Financial Statements, Captions [Line Items]
Net income	$ 21,123	$ 3,705	$ 37,138	$ 28,693
Unrealized gain (loss) on securities, net of tax of ($13), $20, ($60) and $32	(38)	33	(179)	53
Comprehensive income	21,085	3,738	36,959	28,746
Less: Comprehensive income attributable to non-controlling interest	2,224	0	4,586	0
Comprehensive income attributable to Unit Corporation	18,861	3,738	32,373	28,746
Consolidating Adjustments [Member]
Condensed Financial Statements, Captions [Line Items]
Net income	(30,263)	(12,978)	(76,794)	(36,763)
Unrealized gain (loss) on securities, net of tax of ($13), $20, ($60) and $32	0	0	0	0
Comprehensive income	(30,263)	(12,978)	(76,794)	(36,763)
Less: Comprehensive income attributable to non-controlling interest	0	0	0	0
Comprehensive income attributable to Unit Corporation	(30,263)	(12,978)	(76,794)	(36,763)
Parent [Member]
Condensed Financial Statements, Captions [Line Items]
Net income	18,899	3,705	32,552	28,693
Unrealized gain (loss) on securities, net of tax of ($13), $20, ($60) and $32	0	0	0	0
Comprehensive income	18,899	3,705	32,552	28,693
Less: Comprehensive income attributable to non-controlling interest	0	0	0	0
Comprehensive income attributable to Unit Corporation	18,899	3,705	32,552	28,693
Combined Guarantor Subsidiaries [Member]
Condensed Financial Statements, Captions [Line Items]
Net income	28,785	12,102	72,465	35,320
Unrealized gain (loss) on securities, net of tax of ($13), $20, ($60) and $32	(38)	33	(179)	53
Comprehensive income	28,747	12,135	72,286	35,373
Less: Comprehensive income attributable to non-controlling interest	0	0	0	0
Comprehensive income attributable to Unit Corporation	28,747	12,135	72,286	35,373
Combined Non-Guarantor Subsidiaries [Member]
Condensed Financial Statements, Captions [Line Items]
Net income	3,702	876	8,915	1,443
Unrealized gain (loss) on securities, net of tax of ($13), $20, ($60) and $32	0	0	0	0
Comprehensive income	3,702	876	8,915	1,443
Less: Comprehensive income attributable to non-controlling interest	2,224	0	4,586	0
Comprehensive income attributable to Unit Corporation	$ 1,478	$ 876	$ 4,329	$ 1,443

Supplemental Condensed Consol_7

Supplemental Condensed Consolidated Financial Information (Condensed Consolidating Statements of Cash Flows (Unaudited)) (Details) - USD ($) $ in Thousands	9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017
OPERATING ACTIVITIES:
Net cash provided by (used in) operating activities	$ 236,535	$ 184,792
INVESTING ACTIVITIES:
Capital expenditures	(304,054)	(167,392)
Producing properties and other acquisitions	(769)	(55,429)
Proceeds from disposition of assets	25,316	20,137
Other	0	(1,500)
Net cash provided by (used in) investing activities	(279,507)	(204,184)
FINANCING ACTIVITIES:
Borrowings under credit agreement	71,200	251,401
Payments under credit agreement	(249,200)	(250,100)
Intercompany borrowings (advances), net	0	0
Payments on capitalized leases	(2,869)	(2,967)
Proceeds from investments of non-controlling interests	300,000	0
Contributions from Unit	0	0
Transaction costs associated with non-controlling interests	(2,303)	0
Proceeds from issuance of common stock, net of issuance costs	0	18,623
Book overdrafts	17,000	2,364
Net cash provided by (used in) financing activities	133,828	19,321
Net increase (decrease) in cash and cash equivalents	90,856	(71)
Cash and cash equivalents, beginning of period	701	893
Cash and cash equivalents, end of period	91,557	822
Consolidating Adjustments [Member]
OPERATING ACTIVITIES:
Net cash provided by (used in) operating activities	128,605	0
INVESTING ACTIVITIES:
Capital expenditures	0	0
Producing properties and other acquisitions	0	0
Proceeds from disposition of assets	0	0
Other	0	0
Net cash provided by (used in) investing activities	0	0
FINANCING ACTIVITIES:
Borrowings under credit agreement	0	0
Payments under credit agreement	0	0
Intercompany borrowings (advances), net	(128,080)	0
Payments on capitalized leases	0	0
Proceeds from investments of non-controlling interests	0	0
Contributions from Unit	(525)	0
Transaction costs associated with non-controlling interests	0	0
Proceeds from issuance of common stock, net of issuance costs	0	0
Book overdrafts	0	0
Net cash provided by (used in) financing activities	(128,605)	0
Net increase (decrease) in cash and cash equivalents	0	0
Cash and cash equivalents, beginning of period	0	0
Cash and cash equivalents, end of period	0	0
Parent [Member]
OPERATING ACTIVITIES:
Net cash provided by (used in) operating activities	(103,436)	822
INVESTING ACTIVITIES:
Capital expenditures	22	(3,595)
Producing properties and other acquisitions	0	0
Proceeds from disposition of assets	30	955
Other	0	0
Net cash provided by (used in) investing activities	52	(2,640)
FINANCING ACTIVITIES:
Borrowings under credit agreement	69,200	251,401
Payments under credit agreement	(247,200)	(250,100)
Intercompany borrowings (advances), net	248,343	(20,483)
Payments on capitalized leases	0	0
Proceeds from investments of non-controlling interests	102,958	0
Contributions from Unit	0	0
Transaction costs associated with non-controlling interests	(2,303)	0
Proceeds from issuance of common stock, net of issuance costs	0	18,623
Book overdrafts	14,143	2,364
Net cash provided by (used in) financing activities	185,141	1,805
Net increase (decrease) in cash and cash equivalents	81,757	(13)
Cash and cash equivalents, beginning of period	510	517
Cash and cash equivalents, end of period	82,267	504
Combined Guarantor Subsidiaries [Member]
OPERATING ACTIVITIES:
Net cash provided by (used in) operating activities	215,350	149,963
INVESTING ACTIVITIES:
Capital expenditures	(275,434)	(152,055)
Producing properties and other acquisitions	(769)	(55,429)
Proceeds from disposition of assets	25,199	19,124
Other	0	(1,500)
Net cash provided by (used in) investing activities	(251,004)	(189,860)
FINANCING ACTIVITIES:
Borrowings under credit agreement	0	0
Payments under credit agreement	0	0
Intercompany borrowings (advances), net	35,714	39,839
Payments on capitalized leases	0	0
Proceeds from investments of non-controlling interests	0	0
Contributions from Unit	0	0
Transaction costs associated with non-controlling interests	0	0
Proceeds from issuance of common stock, net of issuance costs	0	0
Book overdrafts	0	0
Net cash provided by (used in) financing activities	35,714	39,839
Net increase (decrease) in cash and cash equivalents	60	(58)
Cash and cash equivalents, beginning of period	191	376
Cash and cash equivalents, end of period	251	318
Combined Non-Guarantor Subsidiaries [Member]
OPERATING ACTIVITIES:
Net cash provided by (used in) operating activities	(3,984)	34,007
INVESTING ACTIVITIES:
Capital expenditures	(28,642)	(11,742)
Producing properties and other acquisitions	0	0
Proceeds from disposition of assets	87	58
Other	0	0
Net cash provided by (used in) investing activities	(28,555)	(11,684)
FINANCING ACTIVITIES:
Borrowings under credit agreement	2,000	0
Payments under credit agreement	(2,000)	0
Intercompany borrowings (advances), net	(155,977)	(19,356)
Payments on capitalized leases	(2,869)	(2,967)
Proceeds from investments of non-controlling interests	197,042	0
Contributions from Unit	525	0
Transaction costs associated with non-controlling interests	0	0
Proceeds from issuance of common stock, net of issuance costs	0	0
Book overdrafts	2,857	0
Net cash provided by (used in) financing activities	41,578	(22,323)
Net increase (decrease) in cash and cash equivalents	9,039	0
Cash and cash equivalents, beginning of period	0	0
Cash and cash equivalents, end of period	$ 9,039	$ 0

Subsequent Event (Narrative) (D

Subsequent Event (Narrative) (Details) - Unit Credit Agreement [Member] - USD ($) $ in Millions	Oct. 18, 2018	Sep. 30, 2018	Apr. 02, 2018	Mar. 31, 2018
Subsequent Event [Line Items]
Credit facility maturity date		April 10, 2020
Line Of Credit Facility Lender Determined Amount [Member]
Subsequent Event [Line Items]
Credit facility current credit amount			$ 425	$ 475
Line Of Credit Facility Commitment Amount [Member]
Subsequent Event [Line Items]
Credit facility current credit amount			$ 425	$ 475
Fifth Amendment to Credit Agreement [Member] | Subsequent Event [Member]
Subsequent Event [Line Items]
Fifth Amendment changes	The Fifth Amendment, among other things, (i) extends the term of the Unit credit agreement to October 18, 2023, subject to certain conditions; (ii) reduces the pricing for borrowing and non-use fees; and (iii) eliminates the requirement that the company maintain a senior indebtedness to consolidated EBITDA ratio.
Credit facility maturity date	October 18, 2023
Fifth Amendment to Credit Agreement [Member] | Line Of Credit Facility Lender Determined Amount [Member] | Subsequent Event [Member]
Subsequent Event [Line Items]
Credit facility current credit amount	$ 425
Fifth Amendment to Credit Agreement [Member] | Line Of Credit Facility Commitment Amount [Member] | Subsequent Event [Member]
Subsequent Event [Line Items]
Credit facility current credit amount	$ 425