Ultra Petroleum 10-Q 30 Oct 14 2014 Q3 Quarterly report Financial data

Document_and_Entity_Informatio

Document and Entity Information (USD $)	9 Months Ended
	Sep. 30, 2014	Oct. 21, 2014	Jun. 30, 2013
Document and Entity Information	'	'	'
Entity Registrant Name	'Ultra Petroleum Corp.	'	'
Entity Central Index Key	'0001022646	'	'
Document Type	'10-Q	'	'
Document Period End Date	30-Sep-14	'	'
Amendment Flag	'false	'	'
Current Fiscal Year End Date	'--12-31	'	'
Entity Well-known Seasoned Issuer	'Yes	'	'
Entity Voluntary Filers	'No	'	'
Entity Current Reporting Status	'Yes	'	'
Entity Filer Category	'Large Accelerated Filer	'	'
Entity Public Float	'	'	$3,031,908,251
Entity Common Stock, Shares Outstanding	'	153,210,602	'
Document Fiscal Year Focus	'2014	'	'
Document Fiscal Period Focus	'Q3	'	'

Consolidated_Statement_of_Oper

Consolidated Statement of Operations (USD $)	3 Months Ended		9 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013
Revenues [Abstract]	'	'	'	'
Natural gas sales	$211,853	$191,453	$711,965	$628,438
Oil sales	76,755	29,752	199,005	79,769
Oil and Gas Revenue	288,608	221,205	910,970	708,207
Operating Expenses [Abstract]	'	'	'	'
Lease operating expenses	23,392	16,213	67,363	52,544
LGS operating lease expense	5,076	5,000	15,229	15,000
Production taxes	23,729	18,078	74,254	54,640
Gathering fees	14,916	12,682	41,073	38,400
Transportation charges	20,034	20,955	57,882	61,913
Depletion, depreciation and amoritzation	76,289	59,401	204,810	180,993
General and administrative	6,233	4,060	14,736	15,897
Costs and Expenses	169,669	136,389	475,347	419,387
Operating Income (Loss)	118,939	84,816	435,623	288,820
Other Nonoperating Income (Expense) [Abstract]	'	'	'	'
Interest Expense, Debt	-29,599	-25,174	-83,960	-76,176
Gain (loss) on commodity derivatives	32,052	2,074	-28,323	-20,551
Deferred gain on sale of liquids gathering system	2,638	2,638	7,915	7,914
Other income (expense) net	-56	-63	-54	-50
Other Nonoperating Income (Expense)	5,035	-20,525	-104,422	-88,863
Income (Loss) from Continuing Operations before Equity Method Investments, Income Taxes, Extraordinary Items, Cumulative Effects of Changes in Accounting Principles, Noncontrolling Interest	123,974	64,291	331,201	199,957
Income Tax Expense (Benefit)	-1,383	381	-1,924	3,240
Net Income (Loss)	$125,357	$63,910	$333,125	$196,717
Earnings Per Share, Basic [Abstract]	'	'	'	'
Earnings Per Share, Basic	$0.82	$0.42	$2.18	$1.29
Fully Diluted Earnings per Share:	'	'	'	'
Earnings Per Share, Diluted	$0.81	$0.41	$2.15	$1.27
Weighted Average Number of Shares Outstanding, Basic	153,213	152,976	153,145	152,957
Weighted Average Number of Shares Outstanding, Diluted	154,859	154,512	154,771	154,366

Consolidated_Balance_Sheets

Consolidated Balance Sheets (USD $)	Sep. 30, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Assets, Current [Abstract]	'	'
Cash and cash equivalents	$1,398	$10,664
Restricted cash	117	119
Oil and gas revenue receivable	96,080	84,095
Joint interest billing and other receivables	19,456	17,725
Derivative assets	2,859	1,415
Other current assets	16,967	14,613
Assets, Current	136,877	128,631
Oil And Gas Properties Net Using Full Cost Method Of Accounting [Abstract]	'	'
Proven	3,420,119	2,008,538
Unproven properties not being amortized	385,843	413,073
Property, plant and equipment, net	32,575	216,909
Deferred tax assets	6	6
Deferred financing costs and other	28,507	18,162
Assets	4,003,927	2,785,319
Liabilities, Current [Abstract]	'	'
Accounts payable	75,806	54,806
Accrued liabilities	80,412	79,811
Current portion of long term debt	100,000	0
Production taxes payable	46,227	40,538
Interest payable	18,052	31,865
Derivative Liabilities, Current	2,116	27,291
Capital cost accrual	51,844	173,165
Liabilities, Current	374,457	407,476
Long-term debt	3,326,000	2,470,000
Deferred gain on sale of liquids gathering system	139,486	147,401
Other long-term obligations	158,786	91,932
Commitments and contingencies	'	'
Stockholders' Equity Attributable to Parent [Abstract]	'	'
Common Stock, Value, Issued	493,086	487,273
Treasury Stock, Value	-277	-1,961
Retained loss	-487,611	-816,802
Total shareholders' deficit	5,198	-331,490
Liabilities and Stockholders' Equity	$4,003,927	$2,785,319

Consolidated_Balance_Sheets_Pa

Consolidated Balance Sheets (Parenthetical) (USD $)	9 Months Ended	12 Months Ended
	Sep. 30, 2014	Dec. 31, 2013
Statement of Financial Position [Abstract]	'	'
Common Stock, No Par Value	'	'
Common stock, shares authorized	'unlimited	'unlimited
Common Stock, Shares, Issued	153,206,710	152,990,123
Common Stock, Shares, Outstanding	153,206,710	152,990,123

Consolidated_Statements_of_Cas

Consolidated Statements of Cash Flows (USD $)	9 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2014	Sep. 30, 2013
Net Cash Provided by (Used in) Operating Activities [Abstract]	'	'
Net Income (Loss)	$333,125	$196,717
Adjustments to Reconcile Net Income (Loss) to Cash Provided by (Used in) Operating Activities [Abstract]	'	'
Depletion, depreciation and amoritzation	204,810	180,993
Deferred gain on sale of liquids gathering system	-7,915	-7,914
Unrealized Gain (Loss) on Derivatives	-26,620	-523
Stock compensation	3,500	6,625
Other	3,204	1,678
Increase (Decrease) in Operating Capital [Abstract]	'	'
Restricted cash	2	2
Accounts receivable	-18,230	22,314
Other current assets	-5,871	510
Accounts payable	26,205	-23,292
Accrued liabilities	-11,897	-22,610
Production taxes payable	5,757	-9,521
Interest payable	-13,813	-21,525
Other long-term obligations	17,401	12,745
Income taxes payable receivable	5,504	-9,128
Net Cash Provided by (Used in) Operating Activities	515,162	327,071
Net Cash Provided by (Used in) Investing Activities [Abstract]	'	'
Acquisition Costs	-891,075	0
Oil and gas property expenditures	-441,798	-283,621
Gathering system expenditures	-6,842	-5,137
Change in capital cost accrual	-120,639	-64,451
Proceeds from Sale of Productive Assets	0	-129
Inventory	815	617
Purchase of Capital Assets	-5,327	-415
Net Cash Provided by (Used in) Investing Activities	-1,464,866	-353,136
Net Cash Provided by (Used in) Financing Activities [Abstract]	'	'
Borrowings on long-term debt	833,000	653,000
Payments on long-term debt	-727,000	-630,000
Proceeds from issuance of Senior Notes	850,000	0
Deferred financing costs	-13,317	0
Repurchased shares - net share settlements	-3,015	-5,324
Proceeds from exercise of options	770	0
Net Cash Provided by (Used in) Financing Activities	940,438	17,676
Cash and Cash Equivalents, Period Increase (Decrease)	-9,266	-8,389
Cash and Cash Equivalents, at Carrying Value	10,664	12,921
Cash and Cash Equivalents, at Carrying Value	1,398	4,532
SUPPLEMENTAL INFORMATION:	'	'
Non-cash investing activities - oil and gas properties	$20,000	$12,651

Description_of_the_Business

Description of the Business	9 Months Ended
	Sep. 30, 2014
Description Of Business [Abstract]	'
Organization, Consolidation and Presentation of Financial Statements Disclosure [Text Block]	'
	DESCRIPTION OF THE BUSINESS:
	Ultra Petroleum Corp. (the “Company”) is an independent oil and gas company engaged in the development, production, operation, exploration and acquisition of oil and natural gas properties. The Company is incorporated under the laws of Yukon, Canada. The Company’s principal business activities are developing its long-life natural gas reserves in the Green River Basin of Wyoming – the Pinedale and Jonah fields, its oil reserves in the Uinta Basin in Utah and its natural gas reserves in the Appalachian Basin of Pennsylvania.

Significant_Accounting_Policie

Significant Accounting Policies	9 Months Ended
	Sep. 30, 2014
Significant Accounting Policies [Abstract]	'
Significant Accounting Policies [Text Block]	'
	1.  SIGNIFICANT ACCOUNTING POLICIES:
	The accompanying financial statements, other than the balance sheet data as of December 31, 2013, are unaudited and were prepared from the Company’s records, but do not include all disclosures required by U.S. Generally Accepted Accounting Principles (“GAAP”). Balance sheet data as of December 31, 2013 was derived from the Company’s audited financial statements. The Company’s management believes that these financial statements include all adjustments necessary for a fair presentation of the Company’s financial position and results of operations. All adjustments are of a normal and recurring nature unless specifically noted. The Company prepared these statements on a basis consistent with the Company’s annual audited statements and Regulation S-X. Regulation S-X allows the Company to omit some of the footnote and policy disclosures required by generally accepted accounting principles and normally included in annual reports on Form 10-K. You should read these interim financial statements together with the financial statements, summary of significant accounting policies and notes to the Company’s most recent annual report on Form 10-K.
	Basis of presentation and principles of consolidation:  The consolidated financial statements include the accounts of the Company and its wholly owned subsidiaries. The Company presents its financial statements in accordance with U.S. GAAP. All inter-company transactions and balances have been eliminated upon consolidation.
	(a) Cash and Cash Equivalents:  The Company considers all highly liquid investments with an original maturity of three months or less to be cash equivalents.
	(b) Restricted Cash:  Restricted cash represents cash received by the Company from production sold where the final division of ownership of the production is unknown or in dispute.
	(c) Property, Plant and Equipment:  Capital assets are recorded at cost and depreciated using the declining-balance method based on their respective useful life. Previously, gathering system expenditures were recorded at cost and depreciated separately from proven oil and gas properties using the straight-line method due to the expectation that they would be used to transport production from probable and possible reserves, as well as from third parties.  However, subsequent to the SWEPI Transaction (See Note 8), the Company’s remaining gathering systems are expected to only be used to transport the Company’s proved volumes and as a result, $91.8 million has been transferred to proven oil and gas properties.
	(d) Oil and Natural Gas Properties:  The Company uses the full cost method of accounting for exploration and development activities as defined by the Securities and Exchange Commission (“SEC”) Release No. 33-8995, Modernization of Oil and Gas Reporting Requirements (“SEC Release No. 33-8995”) and Financial Accounting Standards Board (“FASB”) Accounting Standards Codification (“ASC”) Topic 932, Extractive Activities – Oil and Gas (“FASB ASC 932”). Under this method of accounting, the costs of unsuccessful, as well as successful, exploration and development activities are capitalized as oil and gas properties. This includes any internal costs that are directly related to exploration and development activities but does not include any costs related to production, general corporate overhead or similar activities. The carrying amount of oil and natural gas properties also includes estimated asset retirement costs recorded based on the fair value of the asset retirement obligation when incurred. Gain or loss on the sale or other disposition of oil and natural gas properties is not recognized, unless the gain or loss would significantly alter the relationship between capitalized costs and proved reserves of oil and natural gas attributable to a country.
	The sum of net capitalized costs and estimated future development costs of oil and natural gas properties are amortized using the units-of-production method based on the Company’s proved reserves. Oil and natural gas reserves and production are converted into equivalent units based on relative energy content. Asset retirement obligations are included in the base costs for calculating depletion.
	Under the full cost method, costs of unevaluated properties and major development projects expected to require significant future costs may be excluded from capitalized costs being amortized. The Company excludes significant costs until proved reserves are found or until it is determined that the costs are impaired. Excluded costs, if any, are reviewed quarterly to determine if impairment has occurred. The amount of any impairment is transferred to the capitalized costs being amortized.
	Companies that use the full cost method of accounting for oil and natural gas exploration and development activities are required to perform a ceiling test calculation each quarter. The full cost ceiling test is an impairment test prescribed by SEC Regulation S-X Rule 4-10. The ceiling test is performed quarterly, on a country-by-country basis, utilizing the average of prices in effect on the first day of the month for the preceding twelve month period in accordance with SEC Release No. 33-8995. The ceiling limits such pooled costs to the aggregate of the present value of future net revenues attributable to proved crude oil and natural gas reserves discounted at 10%, plus the lower of cost or market value of unproved properties, less any associated tax effects. If such capitalized costs exceed the ceiling, the Company will record a write-down to the extent of such excess as a non-cash charge to earnings. Any such write-down will reduce earnings in the period of occurrence and results in a lower depletion, depreciation and amortization (“DD&A”) rate in future periods. A write-down may not be reversed in future periods even though higher oil and natural gas prices may subsequently increase the ceiling. The Company did not incur a ceiling test write-down for the nine months ended September 30, 2014 or 2013.
	(e) Derivative Instruments and Hedging Activities:  The Company follows FASB ASC Topic 815, Derivatives and Hedging (“FASB ASC 815”). The Company records the fair value of its commodity derivatives as an asset or liability in the Consolidated Balance Sheets, and records the changes in the fair value of its commodity derivatives in the Consolidated Statements of Income as an unrealized gain or loss on commodity derivatives. The Company does not offset the value of its derivative arrangements with the same counterparty. (See Note 6).
	(f) Income Taxes:  Income taxes are accounted for under the asset and liability method. Deferred tax assets and liabilities are recognized for the future tax consequences attributable to differences between the financial statement carrying amounts of existing assets and liabilities and their respective tax basis and operating loss and tax credit carryforwards. Deferred tax assets and liabilities are measured using enacted tax rates expected to apply to taxable income in the years in which those temporary differences are expected to be recovered or settled. The effect on deferred tax assets and liabilities of a change in tax rates is recognized in income in the period that includes the enactment date. Valuation allowances are recorded related to deferred tax assets based on the “more likely than not” criteria described in FASB ASC Topic 740, Income Taxes. In addition, the Company recognizes the financial statement benefit of a tax position only after determining that the relevant tax authority would more likely than not sustain the position following an audit.
	(g) Earnings Per Share:  Basic earnings per share is computed by dividing net earnings attributable to common stockholders by the weighted average number of common shares outstanding during each period. Diluted earnings per share is computed by adjusting the average number of common shares outstanding for the dilutive effect, if any, of common stock equivalents. The Company uses the treasury stock method to determine the dilutive effect.
			Three Months Ended				Nine Months Ended
			September 30,		September 30,		September 30,		September 30,
			2014		2013		2014		2013
			(Share amounts in 000's)
	Net income	$	125,357	$	63,910	$	333,125	$	196,717
	Weighted average common shares outstanding - basic		153,213		152,976		153,145		152,957
	Effect of dilutive instruments		1,646		1,536		1,626		1,409
	Weighted average common shares outstanding - fully diluted		154,859		154,512		154,771		154,366
	Net income per common share - basic	$	0.82	$	0.42	$	2.18	$	1.29
	Net income per common share - fully diluted	$	0.81	$	0.41	$	2.15	$	1.27
	Number of shares not included in dilutive earnings per share that would have been anti-dilutive because the exercise price was greater than the average market price of the common
	shares		1,295		1,340		1,747		1,353
	(h) Use of Estimates:  Preparation of consolidated financial statements in accordance with U.S. GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities, the disclosure of contingent assets and liabilities at the date of the financial statements, and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates.
	(i) Accounting for Share-Based Compensation:  The Company measures and recognizes compensation expense for all share-based payment awards made to employees and directors, including employee stock options, based on estimated fair values in accordance with FASB ASC Topic 718, Compensation – Stock Compensation.
	(j) Fair Value Accounting:  The Company follows FASB ASC Topic 820, Fair Value Measurements and Disclosures (“FASB ASC 820”), which defines fair value, establishes a framework for measuring fair value under GAAP, and expands disclosures about fair value measurements. This statement applies under other accounting topics that require or permit fair value measurements. See Note 7 for additional information.
	(k) Asset Retirement Obligation:  The initial estimated retirement obligation of properties is recognized as a liability with an associated increase in oil and gas properties for the asset retirement cost. Accretion expense is recognized over the estimated productive life of the related assets. If the fair value of the estimated asset retirement obligation changes, an adjustment is recorded to both the asset retirement obligation and the asset retirement cost. Revisions in estimated liabilities can result from revisions of estimated inflation rates, changes in service and equipment costs and changes in the estimated timing of settling asset retirement obligations. As a full cost company, settlements for asset retirement obligations for abandonment are adjusted to the full cost pool. The asset retirement obligation is included within other long-term obligations in the accompanying Consolidated Balance Sheets.
	(l) Revenue Recognition:  The Company generally sells natural gas and condensate under both long-term and short-term agreements at prevailing market prices and under multi-year contracts that provide for a fixed price of oil and natural gas. The Company recognizes revenues when the oil and natural gas is delivered, which occurs when the customer has taken title and has assumed the risks and rewards of ownership, prices are fixed or determinable and collectability is reasonably assured. The Company accounts for oil and natural gas sales using the “entitlements method.” Under the entitlements method, revenue is recorded based upon the Company’s ownership share of volumes sold, regardless of whether it has taken its ownership share of such volumes. The Company records a receivable or a liability to the extent it receives less or more than its share of the volumes and related revenue. Any amount received in excess of the Company’s share is treated as a liability. If the Company receives less than its entitled share, the underproduction is recorded as a receivable.
	Make-up provisions and ultimate settlements of volume imbalances are generally governed by agreements between the Company and its partners with respect to specific properties or, in the absence of such agreements, through negotiation. The value of volumes over- or under-produced can change based on changes in commodity prices. The Company prefers the entitlements method of accounting for oil and natural gas sales because it allows for recognition of revenue based on its actual share of jointly owned production, results in better matching of revenue with related operating expenses, and provides balance sheet recognition of the estimated value of product imbalances.
	(m) Capitalized Interest: Interest is capitalized on the cost of unevaluated gas and oil properties that are excluded from amortization and actively being evaluated, if any, as well as on work in process relating to gathering systems.
	(n) Capital Cost Accrual:  The Company accrues for exploration and development costs and construction of gathering systems in the period incurred, while payment may occur in a subsequent period.
	(o) Recent Accounting Pronouncements: In August 2014, the FASB issued Accounting Standards Update (“ASU”) No. 2014-15, Disclosure of Uncertainties about an Entity’s Ability to Continue as a Going Concern (“ASU No. 2014-15”) that will require management to evaluate whether there are conditions and events that raise substantial doubt about the Company’s ability to continue as a going concern within one year after the financial statements are issued on both an interim and annual basis. Management will be required to provide certain footnote disclosures if it concludes that substantial doubt exists or when its plans alleviate substantial doubt about the Company’s ability to continue as a going concern. ASU No. 2014-15 becomes effective for annual periods beginning in 2016 and for interim reporting periods starting in the first quarter of 2017. The Company does not expect the adoption of this amendment to have a material impact on its consolidated financial statements.
	In June 2014, the FASB issued ASU No. 2014-09, Revenue from Contracts with Customers (Topic 606) (“ASU No. 2014-09”), which amends the FASB ASC by adding new FASB ASC Topic 606, Revenue from Contracts with Customers, and superseding the revenue recognition requirements in FASB ASC 605, Revenue Recognition, and in most industry-specific topics.  ASU No. 2014-09 provides new guidance concerning recognition and measurement of revenue and requires additional disclosures about the nature, timing and uncertainty of revenue and cash flows arising from contracts with customers.  ASU No. 2014-09 becomes effective at the beginning of 2017.  The Company is still evaluating the impact of ASU No. 2014-09 on its financial position and results of operations.

Oil_and_Gas_Properties_and_Equ

Oil and Gas Properties and Equipment	9 Months Ended
	Sep. 30, 2014
Oil And Gas Properties And Equipment [Abstract]	'
Oil and Gas Exploration and Production Industries Disclosures [Text Block]	'
	2. OIL AND GAS PROPERTIES AND EQUIPMENT:
			September 30,		December 31,
			2014		2013
	Proven Properties:
	Acquisition, equipment, exploration, drilling and environmental costs	$	9,429,430	$	7,817,374
	Less: Accumulated depletion, depreciation and amortization(1)		-6,009,311		-5,808,836
			3,420,119		2,008,538
	Unproven Properties:
	Acquisition and exploration costs not being amortized(1)		385,843		413,073
	Net capitalized costs - oil and gas properties	$	3,805,962	$	2,421,611
	(1)For the nine months ended September 30, 2014 and 2013, total interest on outstanding debt was $100.0 million and $76.7 million, respectively, of which, $16.1 million and $0.5 million, respectively, was capitalized on the cost of unevaluated oil and natural gas properties and on work in process relating to gathering systems.

Long_Term_Liabilities

Long Term Liabilities	9 Months Ended
	Sep. 30, 2014
Long Term Liabilities [Abstract]	'
Long-term Debt [Text Block]	'
	3. DEBT AND OTHER LONG-TERM OBLIGATIONS:
				September 30,		December 31,
				2014		2013
		Short-term debt:
		Senior Notes due March 2015	$	100,000	$	-
		Long-term debt and other obligations:
		Bank indebtedness		566,000		460,000
		Senior Notes		2,760,000		2,010,000
		Other long-term obligations		158,786		91,932
			$	3,584,786	$	2,561,932
	Ultra Resources, Inc. Bank Indebtedness –
	The Company’s subsidiary, Ultra Resources, Inc. (“Ultra Resources”, or “Borrower”), is a party to a senior revolving credit facility with a syndicate of banks led by JP Morgan Chase Bank, N.A. (the “Credit Agreement”). The Credit Agreement provides an initial loan commitment of $1.0 billion, which may be increased up to $1.25 billion at the request of the Borrower and with the consent of lenders who are willing to increase their loan commitments, provides for the issuance of letters of credit of up to $250.0 million in aggregate, and matures in October 2016. With majority (over 50%) lender consent, the term of the consenting lenders’ commitments may be extended for up to two successive one-year periods at the Borrower’s request. At September 30, 2014, the Company had $566.0 million in outstanding borrowings and $434.0 million of unused debt capacity under the Credit Agreement.
	Loans under the Credit Agreement are unsecured and bear interest, at the Borrower’s option, based on (A) a rate per annum equal to the prime rate or the weighted average fed funds rate on overnight transactions during the preceding business day plus 100 basis points, or (B) a base Eurodollar rate, substantially equal to the LIBOR rate, plus a margin based on a grid of the Borrower’s consolidated leverage ratio (200 basis points per annum as of September 30, 2014). The Company also pays commitment fees on the unused commitment under the facility based on a grid of its consolidated leverage ratio.
	The Credit Agreement contains typical and customary representations, warranties, covenants and events of default. The Credit Agreement includes restrictive covenants requiring the Borrower to maintain a consolidated leverage ratio of no greater than three and one half times to one and, as long as the Company’s debt rating is below investment grade, the maintenance of an annual ratio of the net present value of the Company’s oil and gas properties to total funded debt of no less than one and one half times to one. At September 30, 2014, the Company was in compliance with all of its debt covenants under the Credit Agreement.
	Ultra Resources, Inc. Senior Notes –
	Ultra Resources also has outstanding $1.56 billion in principal amount of Senior Notes. Ultra Resources’ Senior Notes rank pari passu with the Company’s Credit Agreement. Payment of the Senior Notes is guaranteed by Ultra Petroleum Corp. and UP Energy Corporation. The Senior Notes are pre-payable in whole or in part at any time following the payment of a make-whole premium and are subject to representations, warranties, covenants and events of default similar to those in the Credit Facility. At September 30, 2014, the Company was in compliance with all of its debt covenants under the Senior Notes.
	Ultra Petroleum Corp. Senior Notes –
	Senior Notes due 2024: On September 18, 2014, the Company issued $850.0 million of 6.125% Senior Notes due 2024 (“2024 Notes”). The 2024 Notes are general, unsecured senior obligations of the Company and mature on October 1, 2024. The 2024 Notes rank equally in right of payment to all existing and future senior indebtedness of the Company and effectively rank junior to all future secured indebtedness of the Company (to the extent of the value of the collateral securing such indebtedness). The 2024 Notes are not guaranteed by the Company’s subsidiaries and so are structurally subordinated to the indebtedness and other obligations of the Company’s subsidiaries. On and after October 1, 2019, the Company may redeem all or, from time to time, a part of the 2024 Notes at the following prices expressed as a percentage of principal amount of the 2024 Notes: (2019 – 103.063%; 2020 – 102.042%; 2021 – 101.021%; and 2022 and thereafter – 100.000%). The 2024 Notes are subject to covenants that restrict the Company’s ability to incur indebtedness, make distributions and other restricted payments, grant liens, use the proceeds of asset sales, make investments and engage in affiliate transactions. In addition, the 2024 Notes contain events of default customary for a senior note financing. At September 30, 2014, the Company was in compliance with all of its debt covenants under the 2024 Notes.
	Senior Notes due 2018: On December 12, 2013, the Company issued $450.0 million of 5.75% Senior Notes due 2018 (“2018 Notes”). The 2018 Notes are general, unsecured senior obligations of the Company and mature on December 15, 2018. The 2018 Notes rank equally in right of payment to all existing and future senior indebtedness of the Company and effectively rank junior to all future secured indebtedness of the Company (to the extent of the value of the collateral securing such indebtedness). The 2018 Notes are not guaranteed by the Company’s subsidiaries and so are structurally subordinated to the indebtedness and other obligations of the Company’s subsidiaries. On and after December 15, 2015, the Company may redeem all or, from time to time, a part of the 2018 Notes at the following prices expressed as a percentage of principal amount of the 2018 Notes: (2015 – 102.875%; 2016 – 101.438%; and 2017 and thereafter – 100.000%). The 2018 Notes are subject to covenants that restrict the Company’s ability to incur indebtedness, make distributions and other restricted payments, grant liens, use the proceeds of asset sales, make investments and engage in affiliate transactions. In addition, the 2018 Notes contain events of default customary for a senior note financing. At September 30, 2014, the Company was in compliance with all of its debt covenants under the 2018 Notes.
	Other long-term obligations:  These costs primarily relate to the long-term portion of production taxes payable and asset retirement obligations.

Share_Based_Compensation

Share Based Compensation	9 Months Ended
	Sep. 30, 2014
Stock Based Compensation [Abstract]	'
Disclosure of Compensation Related Costs, Share-based Payments [Text Block]	'
	4. SHARE BASED COMPENSATION:
	Valuation and Expense Information
					Three Months						Nine Months
					Ended September 30,						Ended September 30,
					2014			2013			2014		2013
		Total cost of share-based payment plans		$	3,896		$	601		$	5,635	$	9,458
		Amounts capitalized in oil and gas properties
		and equipment		$	1,425		$	37		$	2,135	$	2,833
		Amounts charged against income, before
		income tax benefit (provision)		$	2,471		$	564		$	3,500	$	6,625
		Amount of related income tax (expense) benefit
		recognized in income before valuation allowance		$	1,033		$	232		$	1,463	$	2,728
	Changes in Stock Options and Stock Options Outstanding
	The following table summarizes the changes in stock options for the nine months ended September 30, 2014 and the year ended December 31, 2013:
					Weighted
			Number of		Average
			Options		Exercise Price
			(000's)		(US$)
		Balance, December 31, 2012	1,357		$	16.97	to	$	98.87
		Forfeited	-110		$	25.68	to	$	75.18
		Exercised	-1		$	16.97	to	$	16.97
		Balance, December 31, 2013	1,246		$	16.97	to	$	98.87
		Forfeited	-246		$	40.34	to	$	75.18
		Exercised	-44		$	16.97	to	$	25.68
		Balance, September 30, 2014	956		$	25.68	to	$	98.87
	Performance Share Plans:
	Long Term Incentive Plans.  The Company offers a Long Term Incentive Plan (“LTIP”) in order to further align the interests of key employees with shareholders and to give key employees the opportunity to share in the long-term performance of the Company when specific corporate financial and operational goals are achieved. Each LTIP covers a performance period of three years. In 2012, 2013 and 2014, the Compensation Committee (the “Committee”) approved an award consisting of performance-based restricted stock units to be awarded to each participant.
	For each LTIP award, the Committee establishes performance measures at the beginning of each three-year performance period. Under each LTIP, the Committee also establishes a percentage of base salary for each participant which is multiplied by the participant’s base salary at the beginning of the performance period and individual performance level to derive a Long Term Incentive Value as a “target” value. This “target” value corresponds to the number of shares of the Company’s common stock the participant is eligible to receive if the participant is employed by the Company through the date the award vests and if the target level for all performance measures is met. In addition, each participant is assigned threshold and maximum award levels in the event the Company’s actual performance is below or above the target levels. For the LTIP awards in 2012, the Committee established the following performance measures: return on equity, reserve replacement ratio, and production growth.  For the LTIP awards in 2013 and 2014, the Committee established the following performance measures:  return on capital employed, debt level, reserve replacement ratio, and total shareholder return (officers only).
	For the nine months ended September 30, 2014, the Company recognized $4.7 million in pre-tax compensation expense related to the 2012, 2013 and 2014 LTIP awards of restricted stock units as compared to $4.5 million during the nine months ended September 30, 2013 related to the 2011, 2012 and 2013 LTIP awards of restricted stock units. The amounts recognized during the nine months ended September 30, 2014 assume that maximum performance objectives are attained under each of the LTIP plans. If the Company ultimately attains these performance objectives, the associated total compensation, estimated at September 30, 2014, for each of the three year performance periods is expected to be approximately $10.3 million, $12.2 million, and $12.7 million related to the 2012, 2013 and 2014 LTIP awards of restricted stock units, respectively. The 2011 LTIP award of restricted stock units was paid in shares of the Company’s stock to employees during the first quarter of 2014 and totaled $8.4 million (106,437 net shares).

Income_Taxes

Income Taxes	9 Months Ended
	Sep. 30, 2014
Income Taxes [Abstract]	'
Income Tax Disclosure [Text Block]	'
	5. INCOME TAXES:
	The Company’s overall effective tax rate on pre-tax income was different than the statutory rate of 35% due primarily to valuation allowances, state income taxes and other permanent differences.
	The Company has recorded a valuation allowance against substantially all of its net deferred tax asset balance as of September 30, 2014. Some or all of this valuation allowance may be reversed in future periods against future income.

Derivative_Financial_Instrumen

Derivative Financial Instruments	9 Months Ended
	Sep. 30, 2014
Derivative Financial Instruments [Abstract]	'
Derivative Instruments and Hedging Activities Disclosure [Text Block]	'
	6.  DERIVATIVE FINANCIAL INSTRUMENTS:
	Objectives and Strategy: The Company’s major market risk exposure is in the pricing applicable to its natural gas and oil production. Realized pricing is currently driven primarily by the prevailing price for the Company’s natural gas production. Historically, prices received for natural gas production have been volatile and unpredictable. Pricing volatility is expected to continue. As a result of its hedging activities, the Company may realize prices that are less than or greater than the spot prices that it would have received otherwise.
	The Company relies on various types of derivative instruments to manage its exposure to commodity price risk and to provide a level of certainty in the Company’s forward cash flows supporting the Company’s capital investment program.
	The Company’s hedging policy limits the amounts of resources hedged to not more than 50% of its forecast production without Board approval.
	Fair Value of Commodity Derivatives: FASB ASC 815 requires that all derivatives be recognized on the Consolidated Balance Sheets as either an asset or liability and be measured at fair value. Changes in the derivative’s fair value are recognized currently in earnings unless specific hedge accounting criteria are met. The Company does not apply hedge accounting to any of its derivative instruments.
	Derivative contracts that do not qualify for hedge accounting treatment are recorded as derivative assets and liabilities at fair value on the Consolidated Balance Sheets and the associated unrealized gains and losses are recorded as current income or expense in the Consolidated Statements of Income. Unrealized gains or losses on commodity derivatives represent the non-cash change in the fair value of these derivative instruments and do not impact operating cash flows on the cash flow statement. See Note 7 for the detail of the fair value of the following derivatives.
	Commodity Derivative Contracts: At September 30, 2014, the Company had the following open commodity derivative contracts to manage price risk on a portion of its production whereby the Company receives the fixed price for the contract and pays the variable price to the counterparty. The reference prices of these commodity derivative contracts are typically referenced to index prices as published by independent third parties.
	Natural Gas:
	Type		Commodity Reference Price		Remaining Contract Period		Volume - MMBTU/Day		Average Price /MMBTU		Fair Value - September 30, 2014
											Asset/(Liability)
	Fixed price swap		NYMEX-Henry Hub		14-Oct		480,000		$3.90	$	-1,321
	Fixed price swap		NYMEX-Henry Hub		Nov - Dec 2014		85,000		$4.35	$	967
	Crude Oil:
	Type		Commodity Reference Price		Remaining Contract Period		Volume - Bbls/Day		Average Price/Bbl		Fair Value - September 30, 2014
											Asset
	Fixed price swap		NYMEX-WTI		Oct - Dec 2014		4,000		$93.19	$	1,097
	Subsequent to September 30, 2014 and through October 30, 2014, the Company has entered into the following open commodity derivative contracts to manage price risk on a portion of its natural gas production whereby the Company receives the fixed price and pays the variable price:
		Type		Commodity Reference Price		Remaining Contract Period		Volume - MMBTU/Day		Average Price/MMBTU
		Fixed price swap		NYMEX-Henry Hub		Apr - Oct 2015		20,000		$3.88
	The following table summarizes the pre-tax realized and unrealized gain (loss) the Company recognized related to its derivative instruments in the Consolidated Statements of Income for the periods ended September 30, 2014 and 2013:
			For the Three Months				For the Nine Months
			Ended September 30,				Ended September 30,
	Commodity Derivatives:		2014		2013		2014		2013
	Realized loss on commodity derivatives-natural gas (1)	$	-7,219	$	-1,310	$	-48,062	$	-21,074
	Realized loss on commodity derivatives-crude oil (1)		-1,479		-		-6,881		-
	Unrealized gain on commodity derivatives (1)		40,750		3,384		26,620		523
	Total gain (loss) on commodity derivatives	$	32,052	$	2,074	$	-28,323	$	-20,551
	(1) Included in gain (loss) on commodity derivatives in the Consolidated Statements of Income.
	The realized gain or loss on commodity derivatives relates to actual amounts received or paid or to be received or paid under the Company’s derivative contracts and the unrealized gain or loss on commodity derivatives represents the change in the fair value of these derivative instruments over the remaining term of the contract.

Fair_Value_Measurements

Fair Value Measurements	9 Months Ended
	Sep. 30, 2014
Fair Value Disclosure [Abstract]	'
Fair Value Disclosures [Text Block]	'
	7.  FAIR VALUE MEASUREMENTS:
	As required by FASB ASC 820, the Company defines fair value as the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date and establishes a three level hierarchy for measuring fair value. Fair value measurements are classified and disclosed in one of the following categories:
	Level 1: Quoted prices (unadjusted) in active markets for identical assets and liabilities that the Company has the ability to access at the measurement date.
	Level 2: Inputs other than quoted prices included within Level 1 that are either directly or indirectly observable for the asset or liability, including quoted prices for similar assets or liabilities in active markets, quoted prices for identical or similar assets or liabilities in inactive markets, inputs other than quoted prices that are observable for the asset or liability, and inputs that are derived from observable market data by correlation or other means. Instruments categorized in Level 2 include non-exchange traded derivatives such as over-the-counter forwards and swaps.
	Level 3: Unobservable inputs for the asset or liability, including situations where there is little, if any, market activity for the asset or liability.
	The valuation assumptions utilized to measure the fair value of the Company’s commodity derivatives were observable inputs based on market data obtained from independent sources and are considered Level 2 inputs (quoted prices for similar assets, liabilities (adjusted) and market-corroborated inputs).
	The following table presents for each hierarchy level the Company’s assets and liabilities, including both current and non-current portions, measured at fair value on a recurring basis, as of September 30, 2014. The Company has no derivative instruments which qualify for cash flow hedge accounting.
				Level 1		Level 2		Level 3		Total
		Current derivative asset	$	-	$	2,859	$	-	$	2,859
		Current derivative liability	$	-	$	2,116	$	-	$	2,116
	In consideration of counterparty credit risk, the Company assessed the possibility of whether each counterparty to the derivative would default by failing to make any contractually required payments as scheduled in the derivative instrument in determining the fair value. Additionally, the Company considers that it is of substantial credit quality and has the financial resources and willingness to meet its potential repayment obligations associated with the derivative transactions.
	Fair Value of Financial Instruments
	The estimated fair value of financial instruments is the estimated amount at which the instrument could be exchanged currently between willing parties. The carrying amounts reported in the Consolidated Balance Sheets for cash and cash equivalents, accounts receivable, and accounts payable approximate fair value due to the immediate or short-term maturity of these financial instruments. The Company uses available market data and valuation methodologies to estimate the fair value of its debt. The valuation assumptions utilized to measure the fair value of the Company’s debt are considered Level 2 inputs. This disclosure is presented in accordance with FASB ASC Topic 825, Financial Instruments, and does not impact the Company’s financial position, results of operations or cash flows.
				30-Sep-14				31-Dec-13
				Carrying		Estimated		Carrying		Estimated
				Amount		Fair Value		Amount		Fair Value
		5.45% Notes due March 2015, issued 2008	$	100,000	$	101,604	$	100,000	$	105,913
		7.31% Notes due March 2016, issued 2009		62,000		66,118		62,000		70,228
		4.98% Notes due January 2017, issued 2010		116,000		120,363		116,000		126,342
		5.92% Notes due March 2018, issued 2008		200,000		214,234		200,000		226,127
		5.75% Notes due December 2018, issued 2013		450,000		460,511		450,000		466,946
		7.77% Notes due March 2019, issued 2009		173,000		198,868		173,000		211,877
		5.50% Notes due January 2020, issued 2010		207,000		217,388		207,000		229,068
		4.51% Notes due October 2020, issued 2010		315,000		310,157		315,000		323,732
		5.60% Notes due January 2022, issued 2010		87,000		91,048		87,000		95,736
		4.66% Notes due October 2022, issued 2010		35,000		34,055		35,000		35,494
		6.125% Notes due October 2024, issued 2014		850,000		814,958		-		-
		5.85% Notes due January 2025, issued 2010		90,000		94,835		90,000		99,142
		4.91% Notes due October 2025, issued 2010		175,000		169,089		175,000		175,744
		Credit Facility due October 2016		566,000		566,000		460,000		460,000
			$	3,426,000	$	3,459,228	$	2,470,000	$	2,626,349

Completion_of_Acquisition_and_

Completion of Acquisition and Disposition of Assets	9 Months Ended
	Sep. 30, 2014
Business Combination Description Disclosure Abstract	'
Business Combination Disclosure [Text Block]	'
	8. COMPLETION OF ACQUISITION AND DISPOSITION OF ASSETS:
	On September 25, 2014, a wholly owned subsidiary of Ultra Petroleum Corp. completed the acquisition of all producing and non-producing properties (including gathering systems) in the Pinedale field in Sublette County, Wyoming (the “SWEPI Properties”) from SWEPI, LP, an affiliate of Royal Dutch Shell, plc in exchange for certain of the Company’s producing and non-producing properties (including gathering systems) in Pennsylvania (the “Pennsylvania Properties”) and a cash payment of $925.0 million (the “SWEPI Transaction”) pursuant to a Purchase and Sale Agreement dated August 13, 2014. In connection with the transaction, the Company settled certain liabilities with SWEPI, LP that were incurred prior to the effective date. The effective date of the transaction is April 1, 2014.
	On September 18, 2014, the Company issued $850.0 million of 6.125% Senior Notes due 2024 (“2024 Notes”) in order to finance a portion of the purchase price of the SWEPI Transaction. The remainder of the cash payment was funded through borrowings under the Company’s senior revolving credit facility. See Note 3.
	The costs related to the issuance of the 2024 Notes of $13.2 million are included with deferred financing costs and other on the Consolidated Balance Sheets and will be amortized over the term of the 2024 Notes. Additionally, the Company incurred $0.5 million of costs associated with the acquisition, which are included with general and administrative expenses in the Consolidated Statements of Income.
	The SWEPI Properties that we acquired consist primarily of 19,600 net mineral acres in Wyoming and associated oil and gas production and wells and the Pennsylvania Properties that we sold consist primarily of 155,000 net acres in Pennsylvania and associated oil and gas production and wells. The transaction is a strategic repositioning of the Company’s portfolio, and the Company expects the acquisition will lead to improved returns, increased reserves, increased percentage of sales in higher value markets, increased operatorship and increased control of capital allocation.
	The transaction was accounted for as a business combination and after customary effective-date adjustments and closing adjustments, the adjusted cash payment on the closing date of September 25, 2014 was $890.8 million and is subject to further post-closing adjustments. The adjusted cash payment was allocated to assets and liabilities based upon fair values at the closing date as follows:
		Adjusted cash payment				$890,785
		Assets:
			Joint interest billing and other receivables - SWEPI Properties			-4,182
			Other current assets:
				Acquired condensate inventory - SWEPI Properties		819
				Acquired yard inventory - SWEPI Properties		3,515
			Subtotal - Other current assets			4,334
			Proven oil and gas properties			1,033,960
			Property, plant and equipment:
				Divested gathering system - Pennsylvania Properties		-98,580
				Acquired other fixed assets - SWEPI Properties		869
				Divested other fixed assets - Pennsylvania Properties		-50
			Subtotal - Property, plant and equipment			-97,761
		Total assets acquired, net of divested assets				$936,351
		Liabilities:
			Current liabilities:
				Current liabilities - Pennsylvania Properties		8,657
				Current liabilities - SWEPI Properties		-601
			Subtotal - Current liabilities			$8,056
			Other long-term obligations:
				Acquired asset retirement obligations - SWEPI Properties		53,270
				Divested asset retirement obligations - Pennsylvania Properties		-15,760
			Subtotal - Other long-term obligations			37,510
		Total liabilities, net				$45,566
	Contingent consideration
	As part of the SWEPI Transaction, the Company agreed to attempt to extend or renew certain expiring leases in Pennsylvania at its expense.
	Pro Forma Operating Results
	The following pro forma combined results for the three and nine months ended September 30, 2014 and 2013 reflect the consolidated results of operations of the Company as if the SWEPI Transaction and related financing had occurred on January 1, 2013. The pro forma information includes adjustments primarily for revenues and expenses from the acquired SWEPI Properties less revenues and expenses from the divested Pennsylvania Properties as well as depreciation, depletion, amortization and accretion, and interest expense associated with the financing related to the SWEPI Transaction.
	The unaudited pro forma combined financial statements give effect to the events described below:
	The acquisition and divestiture of oil and gas properties in the SWEPI Transaction completed on September 25, 2014
	Issuance of $850.0 million of 6.125% senior notes due 2024 to finance a portion of the SWEPI Transaction, and the related adjustments to interest expense
	Increase in borrowings under the Credit Agreement to finance a portion of the SWEPI Transaction, and the related adjustments to interest expense
	Includes transportation charges of $24.4 million and $26.3 million for the three months ended September 30, 2014 and 2013, respectively, and $74.6 million and $86.9 million for the nine months ended September 30, 2014 and 2013, respectively, incurred with respect to operation of the properties acquired in the SWEPI Transaction that will not be incurred by the Company.
	The pro forma combined financial information is for informational purposes only and is not intended to represent or to be indicative of the combined results of operations that the Company would have reported had the SWEPI Transaction and related financing been completed as of the date set forth in the pro forma combined financial information and should not be taken as indicative of the Company’s future combined results of operations. The actual results may differ significantly from that reflected in the pro forma combined financial information for a number of reasons, including, but not limited to, differences in assumptions used to prepare the pro forma combined financial information and actual results.
		Three Months Ended September 30,					Nine Months Ended September 30,
			2014		2013			2014		2013
	Revenues	$	352,236	$	279,240		$	1,102,487	$	886,347
	Net income	$	127,535	$	47,925		$	319,702	$	139,620
	Post-Acquisition Operating Results
	The amounts of revenues and earnings included in the Company’s Consolidated Statements of Income for the three and nine months ended September 30, 2014 related to the SWEPI Transaction represent activity from September 25, 2014 through September 30, 2014 and are immaterial to the Company’s reported results.

Legal_Proceedings

Legal Proceedings	9 Months Ended
	Sep. 30, 2014
Disclosure Legal Proceedings [Abstract]	'
Legal Proceedings [Text Block]	'
	9.  LEGAL PROCEEDINGS:
	The Company is currently involved in various routine disputes and allegations incidental to its business operations. While it is not possible to determine the ultimate disposition of these matters, the Company believes that the resolution of all such pending or threatened litigation is not likely to have a material adverse effect on the Company’s financial position or results of operations.

Subsequent_Events

Subsequent Events	9 Months Ended
	Sep. 30, 2014
Subsequent Events [Abstract]	'
Schedule of Subsequent Events [Text Block]	'
	10.  SUBSEQUENT EVENTS:
	The Company has evaluated the period subsequent to September 30, 2014 for events that did not exist at the balance sheet date but arose after that date and determined that no subsequent events arose that should be disclosed in order to keep the financial statements from being misleading.

Significant_Accounting_Policie1

Significant Accounting Policies (Policies)	9 Months Ended
	Sep. 30, 2014
Statement Significant Accounting Policies [Abstract]	'
Cash and Cash Equivalents, Policy [Text Block]	'
	(a) Cash and Cash Equivalents:  The Company considers all highly liquid investments with an original maturity of three months or less to be cash equivalents.
Restricted Cash Policy [Text Block]	'
	(b) Restricted Cash:  Restricted cash represents cash received by the Company from production sold where the final division of ownership of the production is unknown or in dispute.
Property, Plant and Equipment, Policy [Text Block]	'
	(c) Property, Plant and Equipment:  Capital assets are recorded at cost and depreciated using the declining-balance method based on their respective useful life. Previously, gathering system expenditures were recorded at cost and depreciated separately from proven oil and gas properties using the straight-line method due to the expectation that they would be used to transport production from probable and possible reserves, as well as from third parties.  However, subsequent to the SWEPI Transaction (See Note 8), the Company’s remaining gathering systems are expected to only be used to transport the Company’s proved volumes and as a result, $91.8 million has been transferred to proven oil and gas properties.
Oil And Natural Gas Properties Policy [Text Block]	'
	(d) Oil and Natural Gas Properties:  The Company uses the full cost method of accounting for exploration and development activities as defined by the Securities and Exchange Commission (“SEC”) Release No. 33-8995, Modernization of Oil and Gas Reporting Requirements (“SEC Release No. 33-8995”) and Financial Accounting Standards Board (“FASB”) Accounting Standards Codification (“ASC”) Topic 932, Extractive Activities – Oil and Gas (“FASB ASC 932”). Under this method of accounting, the costs of unsuccessful, as well as successful, exploration and development activities are capitalized as oil and gas properties. This includes any internal costs that are directly related to exploration and development activities but does not include any costs related to production, general corporate overhead or similar activities. The carrying amount of oil and natural gas properties also includes estimated asset retirement costs recorded based on the fair value of the asset retirement obligation when incurred. Gain or loss on the sale or other disposition of oil and natural gas properties is not recognized, unless the gain or loss would significantly alter the relationship between capitalized costs and proved reserves of oil and natural gas attributable to a country.
	The sum of net capitalized costs and estimated future development costs of oil and natural gas properties are amortized using the units-of-production method based on the Company’s proved reserves. Oil and natural gas reserves and production are converted into equivalent units based on relative energy content. Asset retirement obligations are included in the base costs for calculating depletion.
	Under the full cost method, costs of unevaluated properties and major development projects expected to require significant future costs may be excluded from capitalized costs being amortized. The Company excludes significant costs until proved reserves are found or until it is determined that the costs are impaired. Excluded costs, if any, are reviewed quarterly to determine if impairment has occurred. The amount of any impairment is transferred to the capitalized costs being amortized.
	Companies that use the full cost method of accounting for oil and natural gas exploration and development activities are required to perform a ceiling test calculation each quarter. The full cost ceiling test is an impairment test prescribed by SEC Regulation S-X Rule 4-10. The ceiling test is performed quarterly, on a country-by-country basis, utilizing the average of prices in effect on the first day of the month for the preceding twelve month period in accordance with SEC Release No. 33-8995. The ceiling limits such pooled costs to the aggregate of the present value of future net revenues attributable to proved crude oil and natural gas reserves discounted at 10%, plus the lower of cost or market value of unproved properties, less any associated tax effects. If such capitalized costs exceed the ceiling, the Company will record a write-down to the extent of such excess as a non-cash charge to earnings. Any such write-down will reduce earnings in the period of occurrence and results in a lower depletion, depreciation and amortization (“DD&A”) rate in future periods. A write-down may not be reversed in future periods even though higher oil and natural gas prices may subsequently increase the ceiling. The Company did not incur a ceiling test write-down for the nine months ended September 30, 2014 or 2013.
Derivatives, Policy [Text Block]	'
	(e) Derivative Instruments and Hedging Activities:  The Company follows FASB ASC Topic 815, Derivatives and Hedging (“FASB ASC 815”). The Company records the fair value of its commodity derivatives as an asset or liability in the Consolidated Balance Sheets, and records the changes in the fair value of its commodity derivatives in the Consolidated Statements of Income as an unrealized gain or loss on commodity derivatives. The Company does not offset the value of its derivative arrangements with the same counterparty. (See Note 6).
Income Tax, Policy [Text Block]	'
	(f) Income Taxes:  Income taxes are accounted for under the asset and liability method. Deferred tax assets and liabilities are recognized for the future tax consequences attributable to differences between the financial statement carrying amounts of existing assets and liabilities and their respective tax basis and operating loss and tax credit carryforwards. Deferred tax assets and liabilities are measured using enacted tax rates expected to apply to taxable income in the years in which those temporary differences are expected to be recovered or settled. The effect on deferred tax assets and liabilities of a change in tax rates is recognized in income in the period that includes the enactment date. Valuation allowances are recorded related to deferred tax assets based on the “more likely than not” criteria described in FASB ASC Topic 740, Income Taxes. In addition, the Company recognizes the financial statement benefit of a tax position only after determining that the relevant tax authority would more likely than not sustain the position following an audit.
Earnings Per Share, Policy [Text Block]	'
	(g) Earnings Per Share:  Basic earnings per share is computed by dividing net earnings attributable to common stockholders by the weighted average number of common shares outstanding during each period. Diluted earnings per share is computed by adjusting the average number of common shares outstanding for the dilutive effect, if any, of common stock equivalents. The Company uses the treasury stock method to determine the dilutive effect.
			Three Months Ended				Nine Months Ended
			September 30,		September 30,		September 30,		September 30,
			2014		2013		2014		2013
			(Share amounts in 000's)
	Net income	$	125,357	$	63,910	$	333,125	$	196,717
	Weighted average common shares outstanding - basic		153,213		152,976		153,145		152,957
	Effect of dilutive instruments		1,646		1,536		1,626		1,409
	Weighted average common shares outstanding - fully diluted		154,859		154,512		154,771		154,366
	Net income per common share - basic	$	0.82	$	0.42	$	2.18	$	1.29
	Net income per common share - fully diluted	$	0.81	$	0.41	$	2.15	$	1.27
	Number of shares not included in dilutive earnings per share that would have been anti-dilutive because the exercise price was greater than the average market price of the common
	shares		1,295		1,340		1,747		1,353
Use Of Estimates [Text Block]	'
	(h) Use of Estimates:  Preparation of consolidated financial statements in accordance with U.S. GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities, the disclosure of contingent assets and liabilities at the date of the financial statements, and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates.
Compensation Related Costs, Policy [Text Block]	'
	(i) Accounting for Share-Based Compensation:  The Company measures and recognizes compensation expense for all share-based payment awards made to employees and directors, including employee stock options, based on estimated fair values in accordance with FASB ASC Topic 718, Compensation – Stock Compensation.
Fair Value Measurement Policy [Text Block]	'
	(j) Fair Value Accounting:  The Company follows FASB ASC Topic 820, Fair Value Measurements and Disclosures (“FASB ASC 820”), which defines fair value, establishes a framework for measuring fair value under GAAP, and expands disclosures about fair value measurements. This statement applies under other accounting topics that require or permit fair value measurements. See Note 7 for additional information.
Asset Retirement Obligations and Environmental Cost, Policy [Text Block]	'
	(k) Asset Retirement Obligation:  The initial estimated retirement obligation of properties is recognized as a liability with an associated increase in oil and gas properties for the asset retirement cost. Accretion expense is recognized over the estimated productive life of the related assets. If the fair value of the estimated asset retirement obligation changes, an adjustment is recorded to both the asset retirement obligation and the asset retirement cost. Revisions in estimated liabilities can result from revisions of estimated inflation rates, changes in service and equipment costs and changes in the estimated timing of settling asset retirement obligations. As a full cost company, settlements for asset retirement obligations for abandonment are adjusted to the full cost pool. The asset retirement obligation is included within other long-term obligations in the accompanying Consolidated Balance Sheets.
Revenue Recognition, Policy [Text Block]	'
	(l) Revenue Recognition:  The Company generally sells natural gas and condensate under both long-term and short-term agreements at prevailing market prices and under multi-year contracts that provide for a fixed price of oil and natural gas. The Company recognizes revenues when the oil and natural gas is delivered, which occurs when the customer has taken title and has assumed the risks and rewards of ownership, prices are fixed or determinable and collectability is reasonably assured. The Company accounts for oil and natural gas sales using the “entitlements method.” Under the entitlements method, revenue is recorded based upon the Company’s ownership share of volumes sold, regardless of whether it has taken its ownership share of such volumes. The Company records a receivable or a liability to the extent it receives less or more than its share of the volumes and related revenue. Any amount received in excess of the Company’s share is treated as a liability. If the Company receives less than its entitled share, the underproduction is recorded as a receivable.
	Make-up provisions and ultimate settlements of volume imbalances are generally governed by agreements between the Company and its partners with respect to specific properties or, in the absence of such agreements, through negotiation. The value of volumes over- or under-produced can change based on changes in commodity prices. The Company prefers the entitlements method of accounting for oil and natural gas sales because it allows for recognition of revenue based on its actual share of jointly owned production, results in better matching of revenue with related operating expenses, and provides balance sheet recognition of the estimated value of product imbalances.
Interest Expense, Policy [Text Block]	'
	(m) Capitalized Interest: Interest is capitalized on the cost of unevaluated gas and oil properties that are excluded from amortization and actively being evaluated, if any, as well as on work in process relating to gathering systems.
Capital Cost Accrual Policy [Text Block]	'
	(n) Capital Cost Accrual:  The Company accrues for exploration and development costs and construction of gathering systems in the period incurred, while payment may occur in a subsequent period
Recent Accounting Pronouncements [Policy Text Block]	'
	(o) Recent Accounting Pronouncements: In August 2014, the FASB issued Accounting Standards Update (“ASU”) No. 2014-15, Disclosure of Uncertainties about an Entity’s Ability to Continue as a Going Concern (“ASU No. 2014-15”) that will require management to evaluate whether there are conditions and events that raise substantial doubt about the Company’s ability to continue as a going concern within one year after the financial statements are issued on both an interim and annual basis. Management will be required to provide certain footnote disclosures if it concludes that substantial doubt exists or when its plans alleviate substantial doubt about the Company’s ability to continue as a going concern. ASU No. 2014-15 becomes effective for annual periods beginning in 2016 and for interim reporting periods starting in the first quarter of 2017. The Company does not expect the adoption of this amendment to have a material impact on its consolidated financial statements.
	In June 2014, the FASB issued ASU No. 2014-09, Revenue from Contracts with Customers (Topic 606) (“ASU No. 2014-09”), which amends the FASB ASC by adding new FASB ASC Topic 606, Revenue from Contracts with Customers, and superseding the revenue recognition requirements in FASB ASC 605, Revenue Recognition, and in most industry-specific topics.  ASU No. 2014-09 provides new guidance concerning recognition and measurement of revenue and requires additional disclosures about the nature, timing and uncertainty of revenue and cash flows arising from contracts with customers.  ASU No. 2014-09 becomes effective at the beginning of 2017.  The Company is still evaluating the impact of ASU No. 2014-09 on its financial position and results of operations.

Significant_Accounting_Policie2

Significant Accounting Policies (Tables)	9 Months Ended
	Sep. 30, 2014
Significant Accounting Policies Tables [Abstract]	'
Schedule Of Earnings Per Share	'
			Three Months Ended				Nine Months Ended
			September 30,		September 30,		September 30,		September 30,
			2014		2013		2014		2013
			(Share amounts in 000's)
	Net income	$	125,357	$	63,910	$	333,125	$	196,717
	Weighted average common shares outstanding - basic		153,213		152,976		153,145		152,957
	Effect of dilutive instruments		1,646		1,536		1,626		1,409
	Weighted average common shares outstanding - fully diluted		154,859		154,512		154,771		154,366
	Net income per common share - basic	$	0.82	$	0.42	$	2.18	$	1.29
	Net income per common share - fully diluted	$	0.81	$	0.41	$	2.15	$	1.27
	Number of shares not included in dilutive earnings per share that would have been anti-dilutive because the exercise price was greater than the average market price of the common
	shares		1,295		1,340		1,747		1,353

Oil_and_Gas_Properties_and_Equ1

Oil and Gas Properties and Equipment (Tables)	9 Months Ended
	Sep. 30, 2014
Oil And Gas Properties And Equipment Tables [Abstract]	'
Capitalized Costs Relating to Oil and Gas Producing Activities Disclosure [Text Block]	'
	2. OIL AND GAS PROPERTIES AND EQUIPMENT:
			September 30,		December 31,
			2014		2013
	Proven Properties:
	Acquisition, equipment, exploration, drilling and environmental costs	$	9,429,430	$	7,817,374
	Less: Accumulated depletion, depreciation and amortization(1)		-6,009,311		-5,808,836
			3,420,119		2,008,538
	Unproven Properties:
	Acquisition and exploration costs not being amortized(1)		385,843		413,073
	Net capitalized costs - oil and gas properties	$	3,805,962	$	2,421,611

Outstanding_Debt_and_Other_Lon

Outstanding Debt and Other Long Term Obligations (Tables)	9 Months Ended
	Sep. 30, 2014
Outstanding Debt And Other Long Term Obligations Tables [Abstract]	'
Outstanding Debt And Other Long Term Obligations	'
	3. DEBT AND OTHER LONG-TERM OBLIGATIONS:
				September 30,		December 31,
				2014		2013
		Short-term debt:
		Senior Notes due March 2015	$	100,000	$	-
		Long-term debt and other obligations:
		Bank indebtedness		566,000		460,000
		Senior Notes		2,760,000		2,010,000
		Other long-term obligations		158,786		91,932
			$	3,584,786	$	2,561,932

Share_Based_Compensation_Table

Share Based Compensation (Tables)	9 Months Ended
	Sep. 30, 2014
Share Based Compensation Tables [Abstract]	'
Schedule of Employee Service Share-based Compensation, Allocation of Recognized Period Costs [Text Block]	'
	4. SHARE BASED COMPENSATION:
	Valuation and Expense Information
					Three Months						Nine Months
					Ended September 30,						Ended September 30,
					2014			2013			2014		2013
		Total cost of share-based payment plans		$	3,896		$	601		$	5,635	$	9,458
		Amounts capitalized in oil and gas properties
		and equipment		$	1,425		$	37		$	2,135	$	2,833
		Amounts charged against income, before
		income tax benefit (provision)		$	2,471		$	564		$	3,500	$	6,625
		Amount of related income tax (expense) benefit
		recognized in income before valuation allowance		$	1,033		$	232		$	1,463	$	2,728
Stock Option Activity TextBlock	'
					Weighted
			Number of		Average
			Options		Exercise Price
			(000's)		(US$)
		Balance, December 31, 2012	1,357		$	16.97	to	$	98.87
		Forfeited	-110		$	25.68	to	$	75.18
		Exercised	-1		$	16.97	to	$	16.97
		Balance, December 31, 2013	1,246		$	16.97	to	$	98.87
		Forfeited	-246		$	40.34	to	$	75.18
		Exercised	-44		$	16.97	to	$	25.68
		Balance, September 30, 2014	956		$	25.68	to	$	98.87

Derivative_Financial_Instrumen1

Derivative Financial Instruments (Tables)	9 Months Ended
	Sep. 30, 2014
Derivative Financial Instruments Tables [Abstract]	'
Schedule of Derivative Instruments [Text Block]	'
	Natural Gas:
	Type		Commodity Reference Price		Remaining Contract Period		Volume - MMBTU/Day		Average Price /MMBTU		Fair Value - September 30, 2014
											Asset/(Liability)
	Fixed price swap		NYMEX-Henry Hub		14-Oct		480,000		$3.90	$	-1,321
	Fixed price swap		NYMEX-Henry Hub		Nov - Dec 2014		85,000		$4.35	$	967
	Crude Oil:
	Type		Commodity Reference Price		Remaining Contract Period		Volume - Bbls/Day		Average Price/Bbl		Fair Value - September 30, 2014
											Asset
	Fixed price swap		NYMEX-WTI		Oct - Dec 2014		4,000		$93.19	$	1,097
		Type		Commodity Reference Price		Remaining Contract Period		Volume - MMBTU/Day		Average Price/MMBTU
		Fixed price swap		NYMEX-Henry Hub		Apr - Oct 2015		20,000		$3.88
Gain or loss on derivative instruments	'
			For the Three Months				For the Nine Months
			Ended September 30,				Ended September 30,
	Commodity Derivatives:		2014		2013		2014		2013
	Realized loss on commodity derivatives-natural gas (1)	$	-7,219	$	-1,310	$	-48,062	$	-21,074
	Realized loss on commodity derivatives-crude oil (1)		-1,479		-		-6,881		-
	Unrealized gain on commodity derivatives (1)		40,750		3,384		26,620		523
	Total gain (loss) on commodity derivatives	$	32,052	$	2,074	$	-28,323	$	-20,551
	(1) Included in gain (loss) on commodity derivatives in the Consolidated Statements of Income.

Fair_Value_Measurements_Tables

Fair Value Measurements (Tables)	9 Months Ended
	Sep. 30, 2014
Fair Value Measurements Tables [Abstract]	'
Fair Value By Balance Sheet Grouping [Text Block]	'
				Level 1		Level 2		Level 3		Total
		Current derivative asset	$	-	$	2,859	$	-	$	2,859
		Current derivative liability	$	-	$	2,116	$	-	$	2,116
Schedule of Fair Value of Financial Instruments	'
				30-Sep-14				31-Dec-13
				Carrying		Estimated		Carrying		Estimated
				Amount		Fair Value		Amount		Fair Value
		5.45% Notes due March 2015, issued 2008	$	100,000	$	101,604	$	100,000	$	105,913
		7.31% Notes due March 2016, issued 2009		62,000		66,118		62,000		70,228
		4.98% Notes due January 2017, issued 2010		116,000		120,363		116,000		126,342
		5.92% Notes due March 2018, issued 2008		200,000		214,234		200,000		226,127
		5.75% Notes due December 2018, issued 2013		450,000		460,511		450,000		466,946
		7.77% Notes due March 2019, issued 2009		173,000		198,868		173,000		211,877
		5.50% Notes due January 2020, issued 2010		207,000		217,388		207,000		229,068
		4.51% Notes due October 2020, issued 2010		315,000		310,157		315,000		323,732
		5.60% Notes due January 2022, issued 2010		87,000		91,048		87,000		95,736
		4.66% Notes due October 2022, issued 2010		35,000		34,055		35,000		35,494
		6.125% Notes due October 2024, issued 2014		850,000		814,958		-		-
		5.85% Notes due January 2025, issued 2010		90,000		94,835		90,000		99,142
		4.91% Notes due October 2025, issued 2010		175,000		169,089		175,000		175,744
		Credit Facility due October 2016		566,000		566,000		460,000		460,000
			$	3,426,000	$	3,459,228	$	2,470,000	$	2,626,349

Completion_of_Acquisition_and_1

Completion of Acquisition and Disposition of Assets (Tables)	9 Months Ended
	Sep. 30, 2014
Business Combination Tables [Abstract]	'
Adjusted Cash Payment Allocation Disclosure Table [Text Block]	'
	The transaction was accounted for as a business combination and after customary effective-date adjustments and closing adjustments, the adjusted cash payment on the closing date of September 25, 2014 was $890.8 million and is subject to further post-closing adjustments. The adjusted cash payment was allocated to assets and liabilities based upon fair values at the closing date as follows:
		Adjusted cash payment				$890,785
		Assets:
			Joint interest billing and other receivables - SWEPI Properties			-4,182
			Other current assets:
				Acquired condensate inventory - SWEPI Properties		819
				Acquired yard inventory - SWEPI Properties		3,515
			Subtotal - Other current assets			4,334
			Proven oil and gas properties			1,033,960
			Property, plant and equipment:
				Divested gathering system - Pennsylvania Properties		-98,580
				Acquired other fixed assets - SWEPI Properties		869
				Divested other fixed assets - Pennsylvania Properties		-50
			Subtotal - Property, plant and equipment			-97,761
		Total assets acquired, net of divested assets				$936,351
		Liabilities:
			Current liabilities:
				Current liabilities - Pennsylvania Properties		8,657
				Current liabilities - SWEPI Properties		-601
			Subtotal - Current liabilities			$8,056
			Other long-term obligations:
				Acquired asset retirement obligations - SWEPI Properties		53,270
				Divested asset retirement obligations - Pennsylvania Properties		-15,760
			Subtotal - Other long-term obligations			37,510
		Total liabilities, net				$45,566
Pro Forma Financial Information Disclosure Table [Text Block]	'
	The pro forma combined financial information is for informational purposes only and is not intended to represent or to be indicative of the combined results of operations that the Company would have reported had the SWEPI Transaction and related financing been completed as of the date set forth in the pro forma combined financial information and should not be taken as indicative of the Company’s future combined results of operations. The actual results may differ significantly from that reflected in the pro forma combined financial information for a number of reasons, including, but not limited to, differences in assumptions used to prepare the pro forma combined financial information and actual results.
		Three Months Ended September 30,					Nine Months Ended September 30,
			2014		2013			2014		2013
	Revenues	$	352,236	$	279,240		$	1,102,487	$	886,347
	Net income	$	127,535	$	47,925		$	319,702	$	139,620

Significant_Accounting_Policie3

Significant Accounting Policies (Details) (USD $)	3 Months Ended		9 Months Ended
Share data in Thousands, except Per Share data, unless otherwise specified	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013
Significant Accounting Policies Details [Abstract]	'	'	'	'
Gathering SystemTransferred To Proven Properties	$91,800,000	'	$91,800,000	'
Discount Rate Future Net Revenues	'	'	10.00%	'
Earnings Per Share Reconciliation [Abstract]	'	'	'	'
Net Income (Loss)	$125,357,000	$63,910,000	$333,125,000	$196,717,000
Weighted Average Number of Shares Outstanding, Basic	153,213	152,976	153,145	152,957
Incremental Common Shares Attributable to Share-based Payment Arrangements	1,646	1,536	1,626	1,409
Weighted Average Number of Shares Outstanding, Diluted	154,859	154,512	154,771	154,366
Earnings Per Share, Basic	$0.82	$0.42	$2.18	$1.29
Earnings Per Share, Diluted	$0.81	$0.41	$2.15	$1.27
Antidilutive Securities Excluded from Computation of Earnings Per Share, Amount	1,295	1,340	1,747	1,353

Oil_and_Gas_Properties_and_Equ2

Oil and Gas Properties and Equipment (Details) (USD $)	9 Months Ended
	Sep. 30, 2014	Sep. 30, 2013	Dec. 31, 2013
Proven Properties [Abstract]	'	'	'
Acquisition, equipment, exploration, drilling and environmental costs	$9,429,430,000	'	$7,817,374,000
Capitalized Costs, Accumulated Depreciation, Depletion, Amortization and Valuation Allowance for Relating to Oil and Gas Producing Activities	-6,009,311,000	'	-5,808,836,000
Proved	3,420,119,000	'	2,008,538,000
Capitalized Costs of Unproved Properties Excluded from Amortization [Abstract]	'	'	'
Oil Gas Properties Using Full Cost Method Accounting Unproved	385,843,000	'	413,073,000
Capitalized Costs, Oil and Gas Producing Activities, Net	3,805,962,000	'	2,421,611,000
Interest Expense, Borrowings	100,000,000	76,700,000	'
Interest Costs, Capitalized During Period	$16,100,000	$500,000	'

Recovered_Sheet1

Outstanding Debt And Other Long Term Obligations (Details) (USD $)	9 Months Ended
	Sep. 30, 2014	Dec. 31, 2013
Short-term Debt [Abstract]	'	'
Current portion of long term debt	$100,000,000	$0
Long Term Obligations [Abstract]	'	'
Notes Payable to Bank	566,000,000	460,000,000
Other Notes Payable	2,760,000,000	2,010,000,000
Other Liabilities, Noncurrent	158,786,000	91,932,000
Total outstanding debt and other long term obligations	3,584,786,000	2,561,932,000
Senior Credit Facility Details [Abstract]	'	'
Revolving Bank Loan Comitment Value	1,000,000,000	'
Max Revolving Bank Loan Comitment Value	1,250,000,000	'
Letters Of Credit Available Credit Facility	250,000,000	'
Credit Facility Lender Consent Requirement	50.00%	'
Notes Payable to Bank	566,000,000	460,000,000
Debt Instrument, Unused Borrowing Capacity, Amount	434,000,000	'
Debt Instrument Interest Rate Terms Prime	1.00%	'
Debt Instrument Interest Rate Terms Libor	2.00%	'
Ultra Resources Inc Senior Notes	'	'
Senior Notes Ultra Resources Inc	1,560,000,000	'
Ultra Petroleum Corp Senior Notes	'	'
Senior Notes Ultra Petroleum Corp Due 2018 Interest Rate	5.75%	'
Senior Notes Ultra Petroleum Corp Due 2018	450,000,000	'
Debt Instrument Call Feature	'On and after December 15, 2015, the Company may redeem all or, from time to time, a part of the 2018 Notes at the following prices expressed as a percentage of principal amount of the 2018 Notes: (2015 b 102.875%; 2016 b 101.438%; and 2017 and thereafter b 100.000%)	'
Senior Notes UltraPetroleum Corp Due 2024	$850,000,000	'
Senior Notes Ultra Petroleum Corp Due 2024 Interest Rate	6.13%	'
Debt Instrument Call Feature Ultra Petroleum Corp Senior Notes Due 2024	'On and after October 1, 2019, the Company may redeem all or, from time to time, a part of the 2024 Notes at the following prices expressed as a percentage of principal amount of the 2024 Notes: (2019 b 103.063%; 2020 b 102.042%; 2021 b 101.021%; and 2022 and thereafter b 100.000%).	'

Share_Based_Compensation_Detai

Share Based Compensation (Details) (USD $)	3 Months Ended		9 Months Ended		12 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013	Dec. 31, 2013	Dec. 31, 2012
Valuation And Expense Information [Abstract]	'	'	'	'	'	'
Total cost of share based payment plans	$3,896	$601	$5,635	$9,458	'	'
Amounts capitalized in oil and gas properties and equipment	1,425	37	2,135	2,833	'	'
Stock compensation	2,471	564	3,500	6,625	'	'
Amount of related income tax benefit recognized in income before valuation allowance	$1,033	$232	$1,463	$2,728	'	'
Share-based Compensation, Shares Authorized under Stock Option Plans, Exercise Price Range [Line Items]	'	'	'	'	'	'
Share-based Compensation, Shares Authorized under Stock Option Plans, Exercise Price Range, Lower Range Limit	'	'	$25.68	'	$16.97	$16.97
Share-based Compensation, Shares Authorized under Stock Option Plans, Exercise Price Range, Upper Range Limit	'	'	$98.87	'	$98.87	$98.87
Forfeited	'	'	-246	'	-110	'
Exercise Price, Lower Range Limit Forfeited	'	'	$40.34	'	$25.68	'
Exercise Price, Upper Range Limit Forfeited	'	'	$75.18	'	$75.18	'
Exercised	'	'	-44	'	-1	'
Exercise Price, Lower Range Limit Exercised	'	'	$16.97	'	$16.97	'
Exercise Price, Upper Range Limit Exercised	'	'	$25.68	'	$16.97	'
Number Of Options [Member]	'	'	'	'	'	'
Share-based Compensation, Shares Authorized under Stock Option Plans, Exercise Price Range [Line Items]	'	'	'	'	'	'
Share-based Compensation, Shares Authorized under Stock Option Plans, Exercise Price Range, Number of Outstanding Options	956	'	956	'	1,246	1,357

Share_Based_Compensation_Textu

Share Based Compensation - Textuals (Details) (USD $)	9 Months Ended
In Millions, except Share data, unless otherwise specified	Sep. 30, 2014	Sep. 30, 2013
Share Based Compensation Details [Abstract]	'	'
Long Term Incentive Program Period	$4.70	$4.50
Long Term Incentive Program Total 2012 Program	10.3	'
Long Term Incentive Program Total 2013 Program	12.2	'
Long Term Incentive Program Total 2014 Program	12.7	'
Long Term Incentive Program Total 2011 Program	$8.40	'
Long Term Incentive Program Total 2011 Program Shares	106,437	'

Income_Taxes_Details

Income Taxes (Details)	9 Months Ended
	Sep. 30, 2014
Statement Income Taxes Details [Abstract]	'
Statutory tax rate	35.00%

Derivative_Financial_Instrumen2

Derivative Financial Instruments (Details) (USD $)	3 Months Ended		9 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013
Commodity Derivatives [Abstract]	'	'	'	'
Realized (loss) gain on commodity derivatives - natural gas	($7,219)	($1,310)	($48,062)	($21,074)
Realized (loss) gain on commodity derivatives - crude oil	-1,479	0	-6,881	0
Unrealized Gain (Loss) on Derivatives	40,750	3,384	26,620	523
Gain loss on commodity derivatives	32,052	2,074	-28,323	-20,551
Swap [Member] | Nymex WTI [Member] | Calendar 2014 [Member]	'	'	'	'
Schedule Of Derivative Instruments [Line Items]	'	'	'	'
Volume per day	4,000	'	4,000	'
Average Price	93.19	'	93.19	'
Fair Value	1,097	'	1,097	'
Swap [Member] | Nymex Henry Hub [Member] | Summer 2015 [Member]	'	'	'	'
Schedule Of Derivative Instruments [Line Items]	'	'	'	'
Volume per day	20,000	'	20,000	'
Average Price	3.88	'	3.88	'
Swap [Member] | Nymex Henry Hub [Member] | Fall 2014 [Member]	'	'	'	'
Schedule Of Derivative Instruments [Line Items]	'	'	'	'
Volume per day	85,000	'	85,000	'
Average Price	4.35	'	4.35	'
Fair Value	967	'	967	'
Swap [Member] | Nymex Henry Hub [Member] | Summer 2014 [Member]	'	'	'	'
Schedule Of Derivative Instruments [Line Items]	'	'	'	'
Volume per day	480,000	'	480,000	'
Average Price	3.9	'	3.9	'
Fair Value	($1,321)	'	($1,321)	'

Derivative_Financial_Instrumen3

Derivative Financial Instrumens (Textuals)	9 Months Ended
	Sep. 30, 2014
Commodity Derivatives Authorization [Abstract]	'
Commodity Derivatives Board Authorization	50.00%

Fair_Value_Measurments_Details

Fair Value Measurments (Details) (USD $)	Sep. 30, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Derivative Assets [Abstract]	'	'
Derivative assets	$2,859	$1,415
Derivative Liabilities [Abstract]	'	'
Derivative liabilities	2,116	27,291
Fair Value, Inputs, Level 2 [Member]	'	'
Derivative Assets [Abstract]	'	'
Derivative assets	2,859	'
Derivative Liabilities [Abstract]	'	'
Derivative liabilities	$2,116	'

Fair_Value_Measurments_Debt_In

Fair Value Measurments - Debt Instruments (Details) (USD $)	9 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2014	Dec. 31, 2013
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'	'
Total outstanding debt	$3,426,000	$2,470,000
Notes Payable, Fair Value Disclosure	3,459,228	2,626,349
Notes Due 2015 [Member]	'	'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'	'
Total outstanding debt	100,000	100,000
Notes Payable, Fair Value Disclosure	101,604	105,913
Debt Instruments Interest Rates	5.45%	'
Notes Due 2018 [Member]	'	'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'	'
Total outstanding debt	200,000	200,000
Notes Payable, Fair Value Disclosure	214,234	226,127
Debt Instruments Interest Rates	5.92%	'
Notes Due December 2018 [Member]	'	'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'	'
Total outstanding debt	450,000	450,000
Notes Payable, Fair Value Disclosure	460,511	466,946
Debt Instruments Interest Rates	5.75%	'
Notes Due 2016 [Member]	'	'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'	'
Total outstanding debt	62,000	62,000
Notes Payable, Fair Value Disclosure	66,118	70,228
Debt Instruments Interest Rates	7.31%	'
Notes Due 2019 [Member]	'	'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'	'
Total outstanding debt	173,000	173,000
Notes Payable, Fair Value Disclosure	198,868	211,877
Debt Instruments Interest Rates	7.77%	'
Notes Due 2017 [Member]	'	'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'	'
Total outstanding debt	116,000	116,000
Notes Payable, Fair Value Disclosure	120,363	126,342
Debt Instruments Interest Rates	4.98%	'
Notes Due January 2020 [Member]	'	'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'	'
Total outstanding debt	207,000	207,000
Notes Payable, Fair Value Disclosure	217,388	229,068
Debt Instruments Interest Rates	5.50%	'
Notes Due January 2022 [Member]	'	'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'	'
Total outstanding debt	87,000	87,000
Notes Payable, Fair Value Disclosure	91,048	95,736
Debt Instruments Interest Rates	5.60%	'
Notes Due January 2025 [Member]	'	'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'	'
Total outstanding debt	90,000	90,000
Notes Payable, Fair Value Disclosure	94,835	99,142
Debt Instruments Interest Rates	5.85%	'
Notes Due October 2020 [Member]	'	'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'	'
Total outstanding debt	315,000	315,000
Notes Payable, Fair Value Disclosure	310,157	323,732
Debt Instruments Interest Rates	4.51%	'
Notes Due October 2022 [Member]	'	'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'	'
Total outstanding debt	35,000	35,000
Notes Payable, Fair Value Disclosure	34,055	35,494
Debt Instruments Interest Rates	4.66%	'
Notes Due October 2024 [Member]	'	'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'	'
Total outstanding debt	850,000	0
Notes Payable, Fair Value Disclosure	814,958	0
Debt Instruments Interest Rates	6.13%	'
Notes Due October 2025 [Member]	'	'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'	'
Total outstanding debt	175,000	175,000
Notes Payable, Fair Value Disclosure	169,089	175,744
Debt Instruments Interest Rates	4.91%	'
Credit Facility	'	'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'	'
Total outstanding debt	566,000	460,000
Notes Payable, Fair Value Disclosure	$566,000	$460,000

Completion_of_Acquisition_and_2

Completion of Acquisition and Dispostion of Assets (Details) (USD $)	3 Months Ended		9 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013
Business Acquisition Pro Forma Information [Abstract]	'	'	'	'
Revenues	$352,236	$279,240	$1,102,487	$886,347
Net Income	127,535	47,925	319,702	139,620
Business Combination Consideration Transferred [Abstract]	'	'	'	'
Adjusted Cash Payment	'	'	890,785	'
Assets [Abstract]	'	'	'	'
Joint Interest Billing and Other Receivables SWEPI Properties	-4,182	'	-4,182	'
Other Current Assets [Abstract]	'	'	'	'
Acquired Condensate Inventory	819	'	819	'
Acquired Yard Inventory	3,515	'	3,515	'
Subtotal Other Current Assets	4,334	'	4,334	'
Proven Oil And Gas Properties	1,033,960	'	1,033,960	'
Property Plant And Equipment	'	'	'	'
Divested Gathering Systems Pennsylvania Properties	-98,580	'	-98,580	'
Acquired Other Fixed Assets SWEPI Properties	869	'	869	'
Divested Other Fixed Assets Pennsylvania Properties	-50	'	-50	'
Subtotal Property Plant And Equipment	-97,761	'	-97,761	'
Total Assets Acquired Net of Divested Assets	936,351	'	936,351	'
Current Liabilities [Abstract]	'	'	'	'
Current Liabilities Pennsylvania Properties	8,657	'	8,657	'
Current Liabilities SWEPI Properties	-601	'	-601	'
Subtotal Current Liabilities	8,056	'	8,056	'
Other Long Term Obligations [Abstract]	'	'	'	'
Acquired Asset Retirement Obligation SWEPI Properties	53,270	'	53,270	'
Divested Asset Retirement Obligation Pennsylvania Properties	-15,760	'	-15,760	'
Subtotal Other Long Term Obligations	37,510	'	37,510	'
Total Liabilities Net	$45,566	'	$45,566	'

Completion_of_Acquisition_and_3

Completion of Acquisition and Dispositon of Assets - Textuals (Details) (USD $)	3 Months Ended		9 Months Ended
	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013
	acre		acre
Business Combination Details [Abstract]	'	'	'	'
Business Combination Gross Purchase Price	$925,000,000	'	$925,000,000	'
Senior Notes UltraPetroleum Corp Due 2024	850,000,000	'	850,000,000	'
Senior Notes Ultra Petroleum Corp Due 2024 Interest Rate	'	'	6.13%	'
Senior Notes Ultra Petroleum Corp Due 2024 Deferred Financing Costs	'	'	13,200,000	'
Business Combination Integration Related Costs	'	'	500,000	'
Gas And Oil Developed Acreage Acquired Net	19,600	'	19,600	'
Gas And Oil Developed And Undeveloped Acreage Divested Net	155,000	'	155,000	'
Adjusted Cash Payment	'	'	890,785,000	'
Business Combination Non Recurring Transportation Charges	$24,400,000	$26,300,000	$74,600,000	$86,900,000