Carrizo Oil & Gas (CRZO) 10-Q 3 Nov 16 2016 Q3 Quarterly report Financial data

Document And Entity Information

Document And Entity Information - shares	9 Months Ended
	Sep. 30, 2016	Oct. 28, 2016
Document And Entity Information [Abstract]
Document Type	10-Q
Amendment Flag	false
Document Period End Date	Sep. 30, 2016
Document Fiscal Year Focus	2,016
Document Fiscal Period Focus	Q3
Entity Registrant Name	CARRIZO OIL & GAS INC
Entity Central Index Key	1,040,593
Current Fiscal Year End Date	--12-31
Entity Filer Category	Large Accelerated Filer
Entity Common Stock, Shares Outstanding		65,129,295

Consolidated Balance Sheets (Un

Consolidated Balance Sheets (Unaudited) - USD ($) $ in Thousands	Sep. 30, 2016	Dec. 31, 2015
Current assets
Cash and cash equivalents	$ 3,235	$ 42,918
Accounts receivable, net	49,294	54,721
Derivative assets, current	20,146	131,100
Other current assets	4,838	3,443
Total current assets	77,513	232,182
Oil and gas properties, full cost method
Proved properties, net	1,127,264	1,369,151
Unproved properties, not being amortized	196,738	335,452
Other property and equipment, net	10,693	12,258
Total property and equipment, net	1,334,695	1,716,861
Deferred income tax assets, noncurrent	0	46,758
Derivative assets, noncurrent	0	1,115
Other assets	8,299	10,330
Total Assets	1,420,507	2,007,246
Current liabilities
Accounts payable	57,302	74,065
Revenues and royalties payable	43,838	67,808
Accrued capital expenditures	68,583	39,225
Accrued interest	20,956	21,981
Deferred income tax liabilities, current	0	46,758
Other current liabilities	39,083	35,647
Total current liabilities	229,762	285,484
Long-term debt	1,333,801	1,236,017
Asset retirement obligations	17,534	16,183
Derivative liabilities, noncurrent	29,354	12,648
Other liabilities	15,415	12,860
Liabilities	1,625,866	1,563,192
Commitments and contingencies
Shareholders’ equity (deficit)
Common stock, $0.01 par value, 90,000,000 shares authorized; 59,117,696 issued and outstanding as of September 30, 2016 and 58,332,993 issued and outstanding as of December 31, 2015	591	583
Additional paid-in capital	1,436,355	1,411,081
Accumulated deficit	(1,642,305)	(967,610)
Total shareholders’ equity (deficit)	(205,359)	444,054
Total Liabilities and Shareholders’ Equity (Deficit)	$ 1,420,507	$ 2,007,246

Consolidated Balance Sheets (U3

Consolidated Balance Sheets (Unaudited) (Parenthetical) - $ / shares	Sep. 30, 2016	Dec. 31, 2015
Statement of Financial Position [Abstract]
Common stock, par value (in dollars per share)	$ 0.01	$ 0.01
Common stock, shares authorized (in shares)	90,000,000	90,000,000
Common stock, shares issued (in shares)	59,117,696	58,332,993
Common stock, shares outstanding (in shares)	59,117,696	58,332,993

Consolidated Statements Of Oper

Consolidated Statements Of Operations (Unaudited) - USD ($) shares in Thousands, $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015
Crude oil revenues	$ 95,154	$ 95,237	$ 254,758	$ 289,552
Natural gas liquids revenues	5,616	3,330	15,119	11,602
Natural gas revenues	10,407	7,670	29,886	28,627
Total revenues	111,177	106,237	299,763	329,781
Costs and Expenses
Lease operating	24,282	22,213	71,071	67,304
Production taxes	4,886	4,264	12,940	13,313
Ad valorem taxes	1,426	2,256	3,950	7,012
Depreciation, depletion and amortization	48,949	81,256	160,492	234,458
General and administrative, net	18,119	4,207	59,046	54,879
(Gain) loss on derivatives, net	(11,744)	(28,752)	29,938	(42,596)
Interest expense, net	21,190	16,208	58,913	51,403
Impairment of proved oil and gas properties	105,057	812,752	576,540	812,752
Loss on extinguishment of debt	0	0	0	38,137
Other expense, net	499	3,516	1,568	10,789
Total Costs and Expenses	212,664	917,920	974,458	1,247,451
Loss From Continuing Operations Before Income Taxes	(101,487)	(811,683)	(674,695)	(917,670)
Income tax benefit	313	102,915	0	140,456
Loss From Continuing Operations	(101,174)	(708,768)	(674,695)	(777,214)
Income From Discontinued Operations, Net of Income Taxes	0	1,121	0	2,225
Net Income (loss)	$ (101,174)	$ (707,647)	$ (674,695)	$ (774,989)
Net Loss Per Common Share - Basic
Income (loss) from continuing operations - basic (in dollars per share)	$ (1.72)	$ (13.75)	$ (11.49)	$ (15.62)
Income (loss) from discontinued operations - basic (in dollars per share)	0	0.02	0	0.04
Income (loss) per share, basic (in dollars per share)	(1.72)	(13.73)	(11.49)	(15.58)
Net Loss Per Common Share - Diluted
Income (loss) from continuing operations - diluted (in dollars per share)	(1.72)	(13.75)	(11.49)	(15.62)
Income (loss) from discontinued operations - diluted (in dollars per share)	0	0.02	0	0.04
Income (loss) per share, diluted (in dollars per share)	$ (1.72)	$ (13.73)	$ (11.49)	$ (15.58)
Weighted Average Common Shares Outstanding
Basic (in shares)	58,945	51,543	58,705	49,742
Diluted (in shares)	58,945	51,543	58,705	49,742

Consolidated Statements Of Cash

Consolidated Statements Of Cash Flows (Unaudited) - USD ($) $ in Thousands	9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015
Net income (loss)	$ (674,695)	$ (774,989)
(Income) loss from discontinued operations, net of income taxes	0	(2,225)
Adjustments to reconcile loss from continuing operations to net cash provided by operating activities from continuing operations
Depreciation, depletion and amortization	160,492	234,458
Impairment of proved oil and gas properties	576,540	812,752
(Gain) loss on derivatives, net	29,938	(42,596)
Cash received for derivative settlements, net	98,820	141,909
Loss on extinguishment of debt	0	38,137
Stock-based compensation expense, net	30,834	9,203
Deferred Income Tax Expense (Benefit), Excluding Excess Tax Benefit From Stock Based Compensation	0	(140,538)
Non-cash interest expense, net	3,105	3,564
Other, net	2,427	4,554
Changes in components of working capital and other assets and liabilities-
Accounts receivable	1,768	27,395
Accounts payable	(20,294)	(18,115)
Accrued liabilities	(7,954)	(5,614)
Other assets and liabilities, net	(3,134)	(3,676)
Net cash provided by operating activities from continuing operations	197,847	284,219
Net cash used in operating activities from discontinued operations	0	(1,247)
Net cash provided by operating activities	197,847	282,972
Cash Flows From Investing Activities
Capital expenditures - oil and gas properties	(346,245)	(541,616)
Proceeds from sales of oil and gas properties, net	15,331	7,934
Other, net	(661)	(5,390)
Net cash used in investing activities from continuing operations	(331,575)	(539,072)
Net cash used in investing activities from discontinued operations	0	(2,125)
Net cash used in investing activities	(331,575)	(541,197)
Cash Flows From Financing Activities
Issuance of senior notes	0	650,000
Tender and redemption of senior notes	0	(626,681)
Payment of deferred purchase payment	0	(150,000)
Borrowings under credit agreement	510,116	1,045,521
Repayments of borrowings under credit agreement	(414,116)	(889,031)
Payments of debt issuance costs	(1,150)	(11,665)
Sale of common stock, net of offering costs	0	231,316
Proceeds from stock options exercised	0	46
Other, net	(805)	(115)
Net cash provided by financing activities from continuing operations	94,045	249,391
Net cash provided by financing activities from discontinued operations	0	0
Net cash provided by financing activities	94,045	249,391
Net Decrease in Cash and Cash Equivalents	(39,683)	(8,834)
Cash and Cash Equivalents, Beginning of Period	42,918	10,838
Cash and cash equivalents, end of period	$ 3,235	$ 2,004

Nature Of Operations

Nature Of Operations	9 Months Ended
	Sep. 30, 2016
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Nature Of Operations	1. Basis of Presentation Nature of Operations Carrizo Oil & Gas, Inc. is a Houston-based energy company which, together with its subsidiaries (collectively, the “Company”), is actively engaged in the exploration, development, and production of oil and gas primarily from resource plays located in the United States. The Company’s current operations are principally focused in proven, producing oil and gas plays primarily in the Eagle Ford Shale in South Texas, the Delaware Basin in West Texas, the Niobrara Formation in Colorado, the Utica Shale in Ohio, and the Marcellus Shale in Pennsylvania. Consolidated Financial Statements The accompanying unaudited interim consolidated financial statements include the accounts of the Company after elimination of intercompany transactions and balances and have been prepared pursuant to the rules and regulations of the U.S. Securities and Exchange Commission (the “SEC”) and therefore do not include all disclosures required for financial statements prepared in conformity with accounting principles generally accepted in the U.S. (“GAAP”). In the opinion of management, these financial statements include all adjustments (consisting of normal recurring accruals and adjustments) necessary to present fairly, in all material respects, the Company’s interim financial position, results of operations and cash flows. However, the results of operations for the periods presented are not necessarily indicative of the results of operations that may be expected for the full year. These financial statements and related notes included in this Quarterly Report on Form 10-Q should be read in conjunction with the Company’s audited Consolidated Financial Statements and related notes included in the Company’s Annual Report on Form 10-K for the year ended December 31, 2015 (“2015 Annual Report”). Certain reclassifications have been made to prior period amounts to conform to the current period presentation. Such reclassifications had no material impact on prior period amounts.

Summary Of Significant Accounti

Summary Of Significant Accounting Policies	9 Months Ended
	Sep. 30, 2016
Accounting Policies [Abstract]
Summary Of Significant Accounting Policies	2. Summary of Significant Accounting Policies The Company has provided a discussion of significant accounting policies, estimates, and judgments in “Note 2. Summary of Significant Accounting Policies” of the Notes to Consolidated Financial Statements in its 2015 Annual Report. There have been no changes to the Company’s significant accounting policies since December 31, 2015 , other than the recently adopted accounting pronouncements described below. Recently Adopted Accounting Pronouncements In November 2015, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update (“ASU”) 2015-17, Balance Sheet Classification of Deferred Taxes (“ASU 2015-17”). ASU 2015-17 requires that all deferred tax liabilities and assets, as well as any related valuation allowance, be classified in the balance sheet as noncurrent. Effective January 1, 2016, the Company early adopted ASU 2015-17 which was applied prospectively and therefore the adoption had no impact on the consolidated balance sheet as of December 31, 2015. In April 2015, the FASB issued ASU 2015-03, Simplifying the Presentation of Debt Issuance Costs (“ASU 2015-03”). ASU 2015-03 is to simplify the presentation of debt issuance costs in financial statements by presenting such costs in the balance sheet as a direct deduction from the related debt rather than as an asset. In August 2015, the FASB issued ASU 2015-15, Interest-Imputation of Interest (Subtopic 835-30) (“ASU 2015-15”), which allows debt issuance costs associated with line-of-credit agreements to be deferred and presented as an asset in the balance sheet, subsequently amortizing the deferred debt issuance costs ratably over the term of the line-of-credit arrangement, regardless of whether there are any outstanding borrowings. Effective January 1, 2016, the Company adopted ASU 2015-03 and ASU 2015-15 and reclassified $19.7 million of unamortized debt issuance costs related to the Company’s senior notes from long-term assets to long-term debt in the consolidated balance sheet as of December 31, 2015. Debt issuance costs associated with the Company’s revolving credit facility remain classified as a long-term asset in the consolidated balance sheets. Recently Issued Accounting Pronouncements In August 2016, the FASB issued ASU No. 2016-15, Statement of Cash Flows (Topic 230) (“ASU 2016-15”), which is intended to reduce diversity in practice in how certain transactions are classified in the statement of cash flows. The guidance addresses eight specific cash flow issues for which current GAAP is either unclear or does not include specific guidance. ASU 2016-15 is effective for interim and annual periods beginning after December 15, 2017, with early adoption permitted, provided that it is adopted in its entirety in the same period. The Company is evaluating ASU 2016-15 to determine what impact adoption of the new standard will have on its consolidated statements of cash flows. In March 2016, the FASB issued ASU No. 2016-09, Compensation - Stock Compensation (Topic 718): Improvements to Employee Share-Based Payment Accounting (“ASU 2016-09”), which amends certain aspects of accounting for share-based payment arrangements. ASU 2016-09 revises or provides alternative accounting for the tax impacts of share-based payment arrangements, forfeitures, minimum statutory tax withholdings, and prescribes certain disclosures to be made in the period of adoption. ASU 2016-09 is effective for interim and annual periods beginning after December 15, 2016, with early adoption permitted. The Company is evaluating ASU 2016-09 to determine what impact adoption of the new standard will have on its consolidated financial statements and related disclosures. In February 2016, the FASB issued ASU No. 2016-02, Leases (Topic 842) (“ASU 2016-02”), which significantly changes accounting for leases by requiring that lessees recognize a right-of-use asset and a related lease liability representing the obligation to make lease payments, for virtually all lease transactions. Additional disclosures about an entity’s lease transactions will also be required. ASU 2016-02 defines a lease as “a contract, or part of a contract, that conveys the right to control the use of identified property, plant or equipment (an identified asset) for a period of time in exchange for consideration.” ASU 2016-02 is effective for interim and annual periods beginning after December 15, 2018 with early adoption permitted. Lessees and lessors are required to recognize and measure leases at the beginning of the earliest period presented in the financial statements using a modified retrospective approach. The Company is evaluating ASU 2016-02 to determine what impact adoption of the new standard will have on its consolidated financial statements and related disclosures. In May 2014, the FASB issued ASU No. 2014-09, Revenue From Contracts With Customers (Topic 606) (“ASU 2014-09”), which will require entities to recognize revenue to depict the transfer of promised goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods or services. ASU 2014-09 will supersede most current guidance related to revenue recognition when it becomes effective. The new standard also will require expanded disclosures regarding the nature, timing, amount and certainty of revenue and cash flows from contracts with customers. ASU 2014-09 is effective for interim and annual periods beginning after December 15, 2017 with early adoption permitted for interim and annual periods beginning after December 31, 2016. Companies are permitted to adopt ASU 2014-09 through the use of either the full retrospective approach or a modified retrospective approach. The Company does not currently intend to early-adopt ASU 2014-09 and has not determined which transition method it will use. The Company is evaluating ASU 2014-09 to determine what impact adoption of the new standard will have on its consolidated financial statements and related disclosures.

Property and Equipment, Net

Property and Equipment, Net	9 Months Ended
	Sep. 30, 2016
Property, Plant and Equipment [Abstract]
Property And Equipment, Net	3. Property and Equipment, Net As of September 30, 2016 and December 31, 2015 , total property and equipment, net consisted of the following: September 30, December 31, (In thousands) Proved properties $4,467,760 $3,976,511 Accumulated depreciation, depletion and amortization and impairments (3,340,496 ) (2,607,360 ) Proved properties, net 1,127,264 1,369,151 Unproved properties, not being amortized Unevaluated leasehold and seismic costs 163,915 280,263 Exploratory wells in progress 2,051 9,432 Capitalized interest 30,772 45,757 Total unproved properties, not being amortized 196,738 335,452 Other property and equipment 23,106 22,677 Accumulated depreciation (12,413 ) (10,419 ) Other property and equipment, net 10,693 12,258 Total property and equipment, net $1,334,695 $1,716,861 Average depreciation, depletion and amortization (“DD&A”) per Boe of proved properties was $12.72 and $24.19 for the three months ended September 30, 2016 and 2015 , respectively, and $13.79 and $23.82 for the nine months ended September 30, 2016 and 2015 , respectively. The Company capitalized internal costs of employee compensation and benefits, including stock-based compensation, directly associated with acquisition, exploration and development activities totaling $2.7 million and $3.1 million for the three months ended September 30, 2016 and 2015 , respectively, and $8.5 million and $14.0 million for the nine months ended September 30, 2016 and 2015 , respectively. Unproved properties, not being amortized, include unevaluated leasehold and seismic costs associated with specific unevaluated properties, the cost of exploratory wells in progress and related capitalized interest. The Company capitalized interest costs associated with its unevaluated leasehold and seismic costs and exploratory well costs totaling $2.9 million and $7.5 million for the three months ended September 30, 2016 and 2015 , respectively, and $13.4 million and $26.2 million for the nine months ended September 30, 2016 and 2015 , respectively. Impairment of Proved Oil and Gas Properties At the end of each quarter, the net book value of oil and gas properties, less related deferred income taxes, are limited to the “cost center ceiling” equal to (i) the sum of (A) the present value of estimated future net revenues from proved oil and gas reserves, less estimated future expenditures to be incurred in developing and producing the proved reserves computed using a discount factor of 10% , (B) the costs of unproved properties not being amortized, and (C) the lower of cost or estimated fair value of unproved properties included in the costs being amortized; less (ii) related income tax effects. Any excess of the net book value of oil and gas properties, less related deferred income taxes, over the cost center ceiling is recognized as an impairment of proved oil and gas properties. An impairment recognized in one period may not be reversed in a subsequent period even if higher commodity prices in the future result in a cost center ceiling in excess of the net book value of oil and gas properties, less related deferred income taxes. The estimated future net revenues used in the cost center ceiling are calculated using the average realized prices for sales of crude oil, natural gas liquids and natural gas on the first calendar day of each month during the 12-month period prior to the end of the current quarter (“12-Month Average Realized Price”), held flat for the life of the production, except where different prices are fixed and determinable from applicable contracts for the remaining term of those contracts. Prices do not include the impact of derivative instruments as the Company elected not to meet the criteria to qualify derivative instruments for hedge accounting treatment. Primarily due to declines in the 12-Month Average Realized Price of crude oil, the Company recognized impairments of proved oil and gas properties for the three and nine months ended September 30, 2016 and 2015 as summarized in the table below: Three Months Ended Nine Months Ended 2016 2015 2016 2015 Impairment of proved oil and gas properties (in thousands) $105,057 $812,752 $576,540 $812,752 End of period price ($/Bbl) $38.36 $56.05 $38.36 $56.05 Beginning of period price ($/Bbl) $39.84 $68.92 $47.24 $92.24 Percent decrease in price (4 %) (19 %) (19 %) (39 %) The Company's estimated range of the fourth quarter cost center ceiling, at the high end, would exceed the net book value of oil and gas properties, less related deferred income taxes, and at the low end, would result in an impairment of proved oil and gas properties of $50.0 million . This estimated range of the fourth quarter cost center ceiling is based on the estimated 12-Month Average Realized Price of crude oil of $39.26 per barrel as of December 31, 2016 , which is based on the average realized price for sales of crude oil on the first calendar day of each month for the first 11 months and an estimate for the twelfth month based on a quoted forward price. Declines in the 12-Month Average Realized Price of crude oil in subsequent quarters would result in a lower present value of the estimated future net revenues from proved oil and gas reserves and may result in additional impairments of proved oil and gas properties.

Income Taxes

Income Taxes	9 Months Ended
	Sep. 30, 2016
Income Tax Disclosure [Abstract]
Income Taxes	4. Income Taxes The Company’s estimated annual effective income tax rates are used to allocate expected annual income tax expense or benefit to interim periods. The rates are the ratio of estimated annual income tax expense or benefit to estimated annual income or loss before income taxes by taxing jurisdiction, except for discrete items, which are significant, unusual or infrequent items for which income taxes are computed and recorded in the interim period in which the discrete item occurs. The estimated annual effective income tax rates are applied to the year-to-date income or loss before income taxes by taxing jurisdiction to determine the income tax expense or benefit allocated to the interim period. The Company updates its estimated annual effective income tax rates on a quarterly basis considering the geographic mix of income or loss attributable to the tax jurisdictions in which the Company operates. The Company’s income tax benefit from continuing operations differs from the income tax benefit computed by applying the U.S. federal statutory corporate income tax rate of 35% to loss from continuing operations before income taxes as follows: Three Months Ended Nine Months Ended 2016 2015 2016 2015 (In thousands) Loss from continuing operations before income taxes ($101,487 ) ($811,683 ) ($674,695 ) ($917,670 ) Income tax benefit at the statutory rate 35,520 284,089 236,143 321,185 State income tax benefit, net of U.S. federal income taxes 575 6,542 3,859 6,321 Deferred tax assets valuation allowance (36,696 ) (187,607 ) (240,897 ) (187,607 ) Texas Franchise Tax rate reduction, net of U.S. federal income taxes — — — 1,671 Other 914 (109 ) 895 (1,114 ) Income tax benefit from continuing operations $313 $102,915 $— $140,456 Deferred Tax Assets Valuation Allowance Deferred tax assets are recorded for net operating losses and temporary differences between the book and tax basis of assets and liabilities expected to produce tax deductions in future periods. The ultimate realization of deferred tax assets is dependent upon the generation of future taxable income during the periods in which those deferred tax assets would be deductible. The Company assesses the realizability of its deferred tax assets on a quarterly basis by considering whether it is more likely than not that all or a portion of the deferred tax assets will not be realized. The Company considers all available evidence (both positive and negative) when determining whether a valuation allowance is required. In making this assessment, the Company evaluated possible sources of taxable income that may be available to realize the deferred tax assets, including projected future taxable income, the reversal of existing temporary differences, taxable income in carryback years and available tax planning strategies. A significant item of objective negative evidence considered was the cumulative historical three year pre-tax loss and a net deferred tax asset position at September 30, 2016 , driven primarily by the impairments of proved oil and gas properties recognized during the second half of 2015 and throughout 2016 , which limits the ability to consider other subjective evidence such as the Company’s potential for future growth. Based on evaluation of the evidence available during the three months ended September 30, 2016 , the Company’s previous conclusion that it is more likely than not the net deferred tax assets will not be realized remained unchanged and an additional valuation allowance of $36.7 million was recorded for the three months ending September 30, 2016 , reducing the net deferred tax assets to zero . This additional valuation allowance increased the total valuation allowance recorded during the nine months ended September 30, 2016 to $240.9 million . The Company will continue to evaluate whether the valuation allowance is needed in future reporting periods. The valuation allowance will remain until the Company can conclude that the net deferred tax assets are more likely than not to be realized. Future events or new evidence which may lead the Company to conclude that it is more likely than not its net deferred tax assets will be realized include, but are not limited to, cumulative historical pre-tax earnings, improvements in crude oil prices, and taxable events that could result from one or more transactions. The valuation allowance does not preclude the Company from utilizing the tax attributes if the Company recognizes taxable income. As long as the Company continues to conclude that the valuation allowance against its net deferred tax assets is necessary, the Company will have no significant deferred income tax expense or benefit.

Long-Term Debt

Long-Term Debt	9 Months Ended
	Sep. 30, 2016
Debt Disclosure [Abstract]
Debt	5. Long-Term Debt Long-term debt consisted of the following as of September 30, 2016 and December 31, 2015 : September 30, December 31, (In thousands) Senior Secured Revolving Credit Facility due 2018 $96,000 $— 7.50% Senior Notes due 2020 600,000 600,000 Unamortized premium for 7.50% Senior Notes 1,080 1,251 Unamortized debt issuance costs for 7.50% Senior Notes (7,950 ) (9,048 ) 6.25% Senior Notes due 2023 650,000 650,000 Unamortized debt issuance costs for 6.25% Senior Notes (9,754 ) (10,611 ) Other long-term debt due 2028 4,425 4,425 Long-term debt $1,333,801 $1,236,017 Senior Secured Revolving Credit Facility The Company has a senior secured revolving credit facility with a syndicate of banks that, as of September 30, 2016 , had a borrowing base of $600.0 million , with $96.0 million of borrowings outstanding at a weighted average interest rate of 2.46% . As of September 30, 2016 , the Company also had $0.4 million in letters of credit outstanding, which reduce the amounts available under the revolving credit facility. The credit agreement governing the revolving credit facility provides for interest-only payments until July 2, 2018, when the credit agreement matures and any outstanding borrowings are due. The borrowing base under the credit agreement is subject to regular redeterminations in the Spring and Fall of each year, as well as special redeterminations described in the credit agreement, in each case which may reduce the amount of the borrowing base. The amount the Company is able to borrow with respect to the borrowing base is subject to compliance with the financial covenants and other provisions of the credit agreement. Each of the capitalized terms which are not defined in this note shall have the meaning given to such terms in the credit agreement. On May 3, 2016, the Company entered into an amendment to the credit agreement (the “Eighth Amendment”) to, among other things (i) replace the Total Debt to EBITDA ratio covenant with a Total Secured Debt to EBITDA ratio covenant that requires such ratio not to exceed 2.00 to 1.00, (ii) add a covenant requiring a minimum EBITDA to Interest Expense ratio of at least 2.50 to 1.00, (iii) reduce the Borrowing Base under the credit facility from $685.0 million to $600.0 million until the next redetermination thereof, (iv) increase the required mortgage coverage on the total value of the oil and gas properties included in the Company’s most recent reserve report from 80% to 90% , (v) require that the Company’s deposit accounts and securities accounts (subject to certain exclusions) become subject to control agreements, (vi) limit the amount of additional senior notes that can be issued by the Company to $400.0 million , (vii) restrict the Company from making borrowings under the credit facility if the Company has or, after giving effect to the borrowing, will have a Consolidated Cash Balance in excess of $50.0 million , (viii) require mandatory prepayment of borrowings to the extent the Consolidated Cash Balance exceeds $50.0 million if either (a) the Company’s ratio of Total Debt to EBITDA exceeds 3.50 to 1.00 or (b) the availability under the credit facility is equal to or less than 20% of the then effective Borrowing Base, (ix) increase the margin on all loans by 0.50% , and (x) increase the commitment fee from 0.375% to 0.50% when utilization of lender commitments is less than 50% . The obligations of the Company under the credit agreement are guaranteed by the Company’s material domestic subsidiaries and are secured by liens on substantially all of the Company’s assets, including a mortgage lien on oil and gas properties having at least 90% of the total value of the oil and gas properties included in the Company’s most recent reserve report. Borrowings outstanding under the credit agreement bear interest at the Company’s option at either (i) a base rate for a base rate loan plus the margin set forth in the table below, where the base rate is defined as the greatest of the prime rate, the federal funds rate plus 0.50% and the adjusted LIBO rate plus 1.00% , or (ii) an adjusted LIBO rate for a Eurodollar loan plus the margin set forth in the table below. The Company also incurs commitment fees as set forth in the table below based on the unused portion of lender commitments, which are included in interest expense, net. Ratio of Outstanding Borrowings and Letters of Credit to Lender Commitments Applicable Margin for Base Rate Loans Applicable Margin for Eurodollar Loans Commitment Fee Less than 25% 1.00% 2.00% 0.500% Greater than or equal to 25% but less than 50% 1.25% 2.25% 0.500% Greater than or equal to 50% but less than 75% 1.50% 2.50% 0.500% Greater than or equal to 75% but less than 90% 1.75% 2.75% 0.500% Greater than or equal to 90% 2.00% 3.00% 0.500% As discussed above, the Company is subject to certain covenants under the terms of the credit agreement, which include the maintenance of the following financial covenants determined as of the last day of each quarter: (1) a ratio of Total Secured Debt to EBITDA of not more than 2.00 to 1.00; (2) a Current Ratio of not less than 1.00 to 1.00; and (3) a ratio of EBITDA to Interest Expense of not less than 2.50 to 1.00. As defined in the credit agreement, EBITDA includes the last four quarters after giving pro forma effect to EBITDA for material acquisitions and dispositions of oil and gas properties, Interest Expense is comprised of the aggregate interest expense paid in cash for the last four quarters, and the Current Ratio includes an add back of the unused portion of lender commitments. As of September 30, 2016 , the ratio of Total Secured Debt to EBITDA was 0.24 to 1.00, the Current Ratio was 2.63 to 1.00 and the ratio of EBITDA to Interest Expense was 4.35 to 1.00. Because the financial covenants are determined as of the last day of each quarter, the ratios can fluctuate significantly period to period as the level of borrowings outstanding under the credit agreement are impacted by the timing of cash flows from operations, capital expenditures, acquisitions and dispositions of oil and gas properties and securities offerings. The credit agreement also places restrictions on the Company and certain of its subsidiaries with respect to additional indebtedness, liens, dividends and other payments to shareholders, repurchases or redemptions of the Company’s common stock, redemptions of senior notes, investments, acquisitions, mergers, asset dispositions, transactions with affiliates, hedging transactions and other matters. The credit agreement is subject to customary events of default, including in connection with a change in control. If an event of default occurs and is continuing, the lenders may elect to accelerate amounts due under the credit agreement (except in the case of a bankruptcy event of default, in which case such amounts will automatically become due and payable).

Commitments And Contingencies

Commitments And Contingencies	9 Months Ended
	Sep. 30, 2016
Commitments and Contingencies Disclosure [Abstract]
Commitments And Contingencies	6. Commitments and Contingencies From time to time, the Company is party to certain legal actions and claims arising in the ordinary course of business. While the outcome of these events cannot be predicted with certainty, management does not currently expect these matters to have a materially adverse effect on the financial position or results of operations of the Company. The results of operations and financial position of the Company continue to be affected from time to time in varying degrees by domestic and foreign political developments as well as legislation and regulations pertaining to restrictions on crude oil and natural gas production, imports and exports, natural gas regulation, tax increases, environmental regulations and cancellation of contract rights. Both the likelihood and overall effect of such occurrences on the Company vary greatly and are not predictable.

Stock-Based Compensation

Stock-Based Compensation	9 Months Ended
	Sep. 30, 2016
Shareholders' Equity [Abstract]
Shareholders' Equity and Share-based Payments	7. Stock-Based Compensation Stock-Based Compensation Expense (Benefit), Net The Company recognized the following stock-based compensation expense (benefit), net for the periods indicated which is reflected as “General and administrative, net” in the consolidated statements of operations: Three Months Ended Nine Months Ended 2016 2015 2016 2015 (In thousands) Restricted stock awards and units $5,487 $6,013 $23,079 $17,242 Stock appreciation rights 3,361 (11,557 ) 9,581 (5,666 ) Performance share awards 722 598 2,052 1,363 9,570 (4,946 ) 34,712 12,939 Less: amounts capitalized to oil and gas properties (1,150 ) (647 ) (3,878 ) (3,736 ) Total stock-based compensation expense (benefit), net $8,420 ($5,593 ) $30,834 $9,203 Income tax benefit (expense) at the U.S. federal statutory rate $2,947 ($1,958 ) $10,792 $3,221

Earnings Per Share

Earnings Per Share	9 Months Ended
	Sep. 30, 2016
Earnings Per Share [Abstract]
Earnings Per Share	8. Loss From Continuing Operations Per Common Share Supplemental loss from continuing operations per common share information is provided below: Three Months Ended Nine Months Ended 2016 2015 2016 2015 (In thousands, except per share amounts) Loss from Continuing Operations ($101,174 ) ($708,768 ) ($674,695 ) ($777,214 ) Basic weighted average common shares outstanding 58,945 51,543 58,705 49,742 Effect of dilutive instruments — — — — Diluted weighted average common shares outstanding 58,945 51,543 58,705 49,742 Loss from Continuing Operations Per Common Share Basic ($1.72 ) ($13.75 ) ($11.49 ) ($15.62 ) Diluted ($1.72 ) ($13.75 ) ($11.49 ) ($15.62 ) For the three and nine months ended September 30, 2016 and 2015 , the Company reported a loss from continuing operations. As a result, the calculation of diluted weighted average common shares outstanding excluded the anti-dilutive effect of 0.7 million and 0.4 million potentially dilutive common shares outstanding for the three months ended September 30, 2016 and 2015 , respectively, and 0.7 million potentially dilutive common shares outstanding for the nine months ended September 30, 2016 and 2015 .

Derivative Instruments

Derivative Instruments	9 Months Ended
	Sep. 30, 2016
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Derivative Instruments	9. Derivative Instruments The Company uses commodity derivative instruments to reduce its exposure to commodity price volatility for a portion of its forecasted crude oil and natural gas production and thereby achieve a more predictable level of cash flows to support the Company’s drilling and completion capital expenditure program. The Company does not enter into derivative instruments for speculative or trading purposes. As of September 30, 2016 , the Company’s commodity derivative instruments consisted of fixed price swaps, costless collars, and purchased and sold call options, which are described below. Fixed Price Swaps: The Company receives a fixed price and pays a variable market price to the counterparties over specified periods for contracted volumes. Costless Collars: A collar is a combination of options including a purchased put option (fixed floor price) and a sold call option (fixed ceiling price) and allows the Company to benefit from increases in commodity prices up to the fixed ceiling price and protect the Company from decreases in commodity prices below the fixed floor price. At settlement, if the market price is below the fixed floor price or is above the fixed ceiling price, the Company receives the fixed price or pays the market price, respectively. If the market price is between the fixed floor price and fixed ceiling price, no payments are due from either party. These contracts were executed contemporaneously with the same counterparties and were premium neutral such that no payments were paid to or received from the counterparties. Sold Call Options : These contracts give the counterparties the right, but not the obligation, to buy contracted volumes from the Company over specified periods and prices in the future. At settlement, if the market price exceeds the fixed price of the call option, the Company pays the counterparty the excess. If the market price settles below the fixed price of the call option, no payment is due from either party. Purchased Call Options : These contracts give the Company the right, but not the obligation, to buy contracted volumes from the counterparties over specified periods and prices in the future. At settlement, if the market price exceeds the fixed price of the call option, the counterparties pay the Company the excess. If the market price settles below the fixed price of the call option, no payment is due from either party. The Company purchases call options contemporaneously with sales of call options to increase the fixed price of existing sold call options and therefore are presented on a net basis in the summary of open crude oil derivative positions below. The following sets forth a summary of the Company’s open crude oil derivative positions at average NYMEX prices as of September 30, 2016 : Period Type of Contract Crude Oil Volumes (in Bbls/d) Weighted Average Floor Price ($/Bbl) Weighted Average Ceiling Price ($/Bbl) Q4 2016 Fixed Price Swaps 9,750 $60.03 Q4 2016 Costless Collars 4,000 $50.00 $76.50 Q1 2017 Fixed Price Swaps 12,000 $50.13 Q2 2017 Fixed Price Swaps 12,000 $50.13 FY 2018 Sold Call Options 2,488 $60.00 FY 2018 Net Sold Call Options 900 $75.00 FY 2019 Sold Call Options 2,975 $62.50 FY 2019 Net Sold Call Options 900 $77.50 FY 2020 Sold Call Options 3,675 $65.00 FY 2020 Net Sold Call Options 900 $80.00 The following sets forth a summary of the Company’s open natural gas derivative positions at average NYMEX prices as of September 30, 2016 : Period Type of Contract Natural Gas Volumes Weighted FY 2017 Sold Call Options 33,000 $3.00 FY 2018 Sold Call Options 33,000 $3.25 FY 2019 Sold Call Options 33,000 $3.25 FY 2020 Sold Call Options 33,000 $3.50 See “Note 13. Subsequent Events” for details of derivative positions entered into subsequent to September 30, 2016 . In February 2015, the Company entered into derivative transactions offsetting its then existing crude oil derivative positions covering the periods from March 2015 through December 2016. As a result of the offsetting derivative transactions, the Company locked in $166.4 million of cash flows, of which $9.3 million and $40.0 million were received due to contract settlements during the three months ended September 30, 2016 and 2015 , respectively, and $36.9 million and $79.9 million during the nine months ended September 30, 2016 and 2015 , respectively, and are included in the “Cash received for derivative settlements, net” in the consolidated statements of cash flows. As of September 30, 2016 , the remaining locked in cash flows are $10.6 million , of which approximately $7.9 million will be received during the fourth quarter of 2016 and approximately $2.7 million will be received in the first quarter of 2017 , as the applicable contracts settle. All of the remaining locked in cash flows are current assets and are classified as “Derivative assets” in the consolidated balance sheets. The derivative assets associated with the offsetting derivative transactions are not subject to price risk. The offsetting derivative transactions are not included in the table above. In February 2016, the Company sold out-of-the-money natural gas call options for the years 2017 through 2020 and used the associated premium value to obtain in-the-money crude oil fixed price swaps with a weighted average price of $50.27 per Bbl on 6,000 Bbls/d for the first half of 2017. These out-of-the-money natural gas call options and in-the-money crude oil fixed price swaps were executed contemporaneously with the same counterparty, therefore, no cash premiums were paid to or received from the counterparty as the premium value associated with the natural gas call options was immediately applied to the crude oil fixed price swaps. In March 2016, the Company sold 6,000 Bbls/d of in-the-money crude oil fixed price swaps for the first half of the year 2017 at a weighted average fixed price of $50.00 per Bbl. The associated net premiums totaled approximately $5.6 million , of which approximately $2.8 million was paid during the second quarter of 2016 and the remaining $2.8 million was paid during the third quarter of 2016 and are included in the “Cash received for derivative settlements, net” in the consolidated statements of cash flows. The Company typically has numerous hedge positions that span several time periods and often result in both fair value asset and liability positions held with that counterparty, which positions are all offset to a single fair value asset or liability at the end of each reporting period, including the deferred premiums associated with its hedge positions. The Company nets its derivative instrument fair values executed with the same counterparty pursuant to ISDA master agreements, which provide for net settlement over the term of the contract and in the event of default or termination of the contract. The fair value of derivative instruments where the Company is in a net asset position with its counterparties as of September 30, 2016 and December 31, 2015 totaled $6.8 million and $119.6 million , respectively, and is summarized by counterparty in the table below: Counterparty September 30, 2016 December 31, 2015 Regions 40 % 9 % Wells Fargo 34 % 35 % Union Bank 26 % 5 % Capital One — % 1 % Societe Generale — % 37 % Citibank — % 13 % Total 100 % 100 % The counterparties to the Company’s derivative instruments are also lenders under the Company’s credit agreement which allows the Company to satisfy any need for margin obligations associated with derivative instruments where the Company is in a net liability position with its counterparties with the collateral securing the credit agreement, thus eliminating the need for independent collateral posting. Because each of the counterparties have investment grade credit ratings, the Company believes it does not have significant credit risk and accordingly does not currently require its counterparties to post collateral to support the net asset positions of its derivative instruments. As such, the Company is exposed to credit risk to the extent of nonperformance by the counterparties to its derivative instruments. Although the Company does not currently anticipate such nonperformance, it continues to monitor the credit ratings of its counterparties.

Fair Value Measurements

Fair Value Measurements	9 Months Ended
	Sep. 30, 2016
Fair Value Disclosures [Abstract]
Fair Value Measurements	10. Fair Value Measurements Accounting guidelines for measuring fair value establish a three-level valuation hierarchy for disclosure of fair value measurements. The valuation hierarchy categorizes assets and liabilities measured at fair value into one of three different levels depending on the observability of the inputs employed in the measurement. The three levels are defined as follows: Level 1 – Observable inputs such as quoted prices in active markets at the measurement date for identical, unrestricted assets or liabilities. Level 2 – Other inputs that are observable directly or indirectly such as quoted prices in markets that are not active, or inputs which are observable, either directly or indirectly, for substantially the full term of the asset or liability. Level 3 – Unobservable inputs for which there is little or no market data and which the Company makes its own assumptions about how market participants would price the assets and liabilities. Assets and Liabilities Measured at Fair Value on a Recurring Basis The following tables summarize the Company’s assets and liabilities measured at fair value on a recurring basis as presented in the consolidated balance sheets as of September 30, 2016 and December 31, 2015 . All items included in the tables below are Level 2 inputs within the fair value hierarchy: September 30, 2016 Gross Amounts Recognized Gross Amounts Offset in the Consolidated Balance Sheets Net Amounts Presented in the Consolidated Balance Sheets (In thousands) Derivative assets Derivative assets-current $31,742 ($11,596 ) $20,146 Derivative assets-non current 1,992 (1,992 ) — Derivative liabilities Other current liabilities (11,596 ) 11,596 — Derivative liabilities-non current (31,346 ) 1,992 (29,354 ) Total ($9,208 ) $— ($9,208 ) December 31, 2015 Gross Amounts Recognized Gross Amounts Offset in the Consolidated Balance Sheets Net Amounts Presented in the Consolidated Balance Sheets (In thousands) Derivative assets Derivative assets-current $159,447 ($28,347 ) $131,100 Derivative assets-non current 10,780 (9,665 ) 1,115 Derivative liabilities Other current liabilities (28,364 ) 28,347 (17 ) Derivative liabilities-non current (22,313 ) 9,665 (12,648 ) Total $119,550 $— $119,550 The fair values of the Company’s derivative assets and liabilities are based on a third-party industry-standard pricing model that uses market data obtained from third-party sources, including quoted forward prices for crude oil and natural gas, discount rates and volatility factors. The fair values are also compared to the values provided by the counterparties for reasonableness and are adjusted for the counterparties’ credit quality for derivative assets and the Company’s credit quality for derivative liabilities. The derivative asset and liability fair values reported in the consolidated balance sheets that pertain to the Company’s derivative instruments are as of the balance sheet date and subsequently change to reflect actual results, changes in market conditions and other factors. However, the fair value of the net derivative asset attributable to the offsetting crude oil derivative transactions are not subject to price risk as changes in the fair value of the original positions are offset by changes in the fair value of the offsetting positions. The Company typically has numerous hedge positions that span several time periods and often result in both derivative assets and liabilities with the same counterparty, which positions are all offset to a single derivative asset or liability in the consolidated balance sheets, including the deferred premiums associated with its hedge positions. The Company nets the fair values of its derivative assets and liabilities associated with derivative instruments executed with the same counterparty pursuant to ISDA master agreements, which provide for net settlement over the term of the contract and in the event of default or termination of the contract. The Company had no transfers into Level 1 and no transfers into or out of Level 2 for the nine months ended September 30, 2016 and 2015 . Fair Value of Other Financial Instruments The Company’s other financial instruments consist of cash and cash equivalents, receivables, payables and long-term debt, which are classified as Level 1 under the fair value hierarchy. The carrying amounts of cash and cash equivalents, receivables, and payables approximate fair value due to the highly liquid or short-term nature of these instruments. The carrying amount of long-term debt associated with borrowings outstanding under the Company’s revolving credit facility approximates fair value as borrowings bear interest at variable rates. The following table presents the carrying amounts of the Company’s senior notes and other long-term debt, net of debt premiums and debt issuance costs, with the fair values of each based on quoted market prices. September 30, 2016 December 31, 2015 Carrying Amount Fair Value Carrying Amount Fair Value (In thousands) 7.50% Senior Notes due 2020 $593,130 $615,000 $592,203 $528,000 6.25% Senior Notes due 2023 640,246 643,500 639,389 533,000 Other long-term debt due 2028 4,425 4,337 4,425 4,182

Condensed Consolidating Financi

Condensed Consolidating Financial Information	9 Months Ended
	Sep. 30, 2016
Condensed Consolidating Financial Information [Abstract]
Condensed Consolidating Financial Information	11. Condensed Consolidating Financial Information The rules of the SEC require that condensed consolidating financial information be provided for a subsidiary that has guaranteed the debt of a registrant issued in a public offering, where the guarantee is full, unconditional and joint and several and where the voting interest of the subsidiary is 100% owned by the registrant. The Company is, therefore, presenting condensed consolidating financial information on a parent company, combined guarantor subsidiaries, combined non-guarantor subsidiaries and consolidated basis and should be read in conjunction with the consolidated financial statements. The financial information may not necessarily be indicative of results of operations, cash flows, or financial position had such guarantor subsidiaries operated as independent entities. CARRIZO OIL & GAS, INC. CONDENSED CONSOLIDATING BALANCE SHEETS (In thousands) (Unaudited) September 30, 2016 Parent Company Combined Guarantor Subsidiaries Combined Non- Guarantor Subsidiaries Eliminations Consolidated Assets Total current assets $2,551,367 $50,479 $— ($2,524,333 ) $77,513 Total property and equipment, net 42,759 1,291,991 3,800 (3,855 ) 1,334,695 Investment in subsidiaries (1,338,051 ) — — 1,338,051 — Other assets 8,143 156 — — 8,299 Total Assets $1,264,218 $1,342,626 $3,800 ($1,190,137 ) $1,420,507 Liabilities and Shareholders’ Deficit Current liabilities $94,952 $2,658,363 $3,800 ($2,527,353 ) $229,762 Long-term liabilities 1,357,911 22,314 — 15,879 1,396,104 Total shareholders’ deficit (188,645 ) (1,338,051 ) — 1,321,337 (205,359 ) Total Liabilities and Shareholders’ Deficit $1,264,218 $1,342,626 $3,800 ($1,190,137 ) $1,420,507 December 31, 2015 Parent Company Combined Guarantor Subsidiaries Combined Non- Guarantor Subsidiaries Eliminations Consolidated Assets Total current assets $2,578,034 $52,067 $— ($2,397,919 ) $232,182 Total property and equipment, net 44,499 1,671,774 3,059 (2,471 ) 1,716,861 Investment in subsidiaries (815,836 ) — — 815,836 — Other assets 74,679 156 — (16,632 ) 58,203 Total Assets $1,881,376 $1,723,997 $3,059 ($1,601,186 ) $2,007,246 Liabilities and Shareholders’ Equity Current liabilities $161,792 $2,521,572 $3,059 ($2,400,939 ) $285,484 Long-term liabilities 1,260,200 18,261 — (753 ) 1,277,708 Total shareholders’ equity 459,384 (815,836 ) — 800,506 444,054 Total Liabilities and Shareholders’ Equity $1,881,376 $1,723,997 $3,059 ($1,601,186 ) $2,007,246 CARRIZO OIL & GAS, INC. CONDENSED CONSOLIDATING STATEMENTS OF OPERATIONS (In thousands) (Unaudited) Three Months Ended September 30, 2016 Parent Company Combined Guarantor Subsidiaries Combined Non- Guarantor Subsidiaries Eliminations Consolidated Total revenues $105 $111,072 $— $— $111,177 Total costs and expenses 28,551 184,047 — 66 212,664 Loss from continuing operations before income taxes (28,446 ) (72,975 ) — (66 ) (101,487 ) Income tax benefit — — — 313 313 Equity in loss of subsidiaries (72,975 ) — — 72,975 — Loss from continuing operations (101,421 ) (72,975 ) — 73,222 (101,174 ) Income from discontinued operations, net of income taxes — — — — — Net loss ($101,421 ) ($72,975 ) $— $73,222 ($101,174 ) Three Months Ended September 30, 2015 Parent Company Combined Guarantor Subsidiaries Combined Non- Guarantor Subsidiaries Eliminations Consolidated Total revenues $235 $106,002 $— $— $106,237 Total costs and expenses (6,718 ) 890,350 — 34,288 917,920 Income (loss) from continuing operations before income taxes 6,953 (784,348 ) — (34,288 ) (811,683 ) Income tax (expense) benefit (25,496 ) 119,847 — 8,564 102,915 Equity in loss of subsidiaries (664,501 ) — — 664,501 — Loss from continuing operations (683,044 ) (664,501 ) — 638,777 (708,768 ) Income from discontinued operations, net of income taxes 1,121 — — — 1,121 Net loss ($681,923 ) ($664,501 ) $— $638,777 ($707,647 ) CARRIZO OIL & GAS, INC. CONDENSED CONSOLIDATING STATEMENTS OF OPERATIONS (In thousands) (Unaudited) Nine Months Ended September 30, 2016 Parent Company Combined Guarantor Subsidiaries Combined Non- Guarantor Subsidiaries Eliminations Consolidated Total revenues $349 $299,414 $— $— $299,763 Total costs and expenses 151,445 822,582 — 431 974,458 Loss from continuing operations before income taxes (151,096 ) (523,168 ) — (431 ) (674,695 ) Income tax benefit — — — — — Equity in loss of subsidiaries (523,168 ) — — 523,168 — Loss from continuing operations (674,264 ) (523,168 ) — 522,737 (674,695 ) Income from discontinued operations, net of income taxes — — — — — Net loss ($674,264 ) ($523,168 ) $— $522,737 ($674,695 ) Nine Months Ended September 30, 2015 Parent Company Combined Guarantor Subsidiaries Combined Non- Guarantor Subsidiaries Eliminations Consolidated Total revenues $1,485 $328,296 $— $— $329,781 Total costs and expenses 116,793 1,101,671 — 28,987 1,247,451 Loss from continuing operations before (115,308 ) (773,375 ) — (28,987 ) (917,670 ) Income tax benefit 17,296 116,006 — 7,154 140,456 Equity in loss of subsidiaries (657,369 ) — — 657,369 — Loss from continuing operations (755,381 ) (657,369 ) — 635,536 (777,214 ) Income from discontinued operations, net of income taxes 2,225 — — — 2,225 Net loss ($753,156 ) ($657,369 ) $— $635,536 ($774,989 ) CARRIZO OIL & GAS, INC. CONDENSED CONSOLIDATING STATEMENTS OF CASH FLOWS (In thousands) (Unaudited) Nine Months Ended September 30, 2016 Parent Company Combined Guarantor Subsidiaries Combined Non- Guarantor Subsidiaries Eliminations Consolidated Net cash provided by (used in) operating activities from continuing operations ($10,882 ) $208,729 $— $— $197,847 Net cash used in investing activities from continuing operations (122,846 ) (331,351 ) (740 ) 123,362 (331,575 ) Net cash provided by financing activities from 94,045 122,622 740 (123,362 ) 94,045 Net cash used in discontinued operations — — — — — Net decrease in cash and cash equivalents (39,683 ) — — — (39,683 ) Cash and cash equivalents, beginning of period 42,918 — — — 42,918 Cash and cash equivalents, end of period $3,235 $— $— $— $3,235 Nine Months Ended September 30, 2015 Parent Company Combined Guarantor Subsidiaries Combined Non- Guarantor Subsidiaries Eliminations Consolidated Net cash provided by (used in) operating activities from continuing operations ($8,817 ) $293,036 $— $— $284,219 Net cash used in investing activities from (396,036 ) (529,046 ) — 386,010 (539,072 ) Net cash provided by financing activities from continuing operations 399,391 236,010 — (386,010 ) 249,391 Net cash used in discontinued operations (3,372 ) — — — (3,372 ) Net decrease in cash and cash equivalents (8,834 ) — — — (8,834 ) Cash and cash equivalents, beginning of period 10,838 — — — 10,838 Cash and cash equivalents, end of period $2,004 $— $— $— $2,004

Supplemental Cash Flow Informat

Supplemental Cash Flow Information	9 Months Ended
	Sep. 30, 2016
Supplemental Cash Flow Elements [Abstract]
Cash Flow, Supplemental Disclosures	12. Supplemental Cash Flow Information Supplemental disclosures to the consolidated statements of cash flows are presented below: Nine Months Ended 2016 2015 (In thousands) Non-cash investing activities: Increase (decrease) in capital expenditure payables and accruals $7,316 ($71,967 ) Other non-cash investing activities (1) 12,468 23,737 (1) Other non-cash investing activities includes items such as property exchanges, capitalized asset retirement obligations, capital lease transactions and other non-cash activity.

Subsequent Events

Subsequent Events	9 Months Ended
	Sep. 30, 2016
Subsequent Events [Abstract]
Subsequent Events	13. Subsequent Events Sanchez Acquisition On October 24, 2016, the Company entered into a purchase and sale agreement with Sanchez Energy Corporation and SN Cotulla Assets, LLC, a subsidiary of Sanchez Energy Corporation, to acquire oil and gas properties in the Eagle Ford Shale primarily in LaSalle, Frio and McMullen Texas counties (the “Sanchez Acquisition”) for a purchase price of approximately $181.0 million in cash, subject to customary purchase price adjustments. The transaction has an effective date of June 1, 2016, and is currently expected to close on or about December 14, 2016. On October 24, 2016, the Company paid $10.0 million as a deposit, which was funded from borrowings under the revolving credit facility that were repaid with net proceeds from the common stock offering discussed below. The remaining purchase price is due on the closing date. The Company intends to fund the remaining purchase price at closing with cash remaining from the common stock offering described below and borrowings under its revolving credit facility. Upon consummation of the Sanchez Acquisition, the Company will become the operator of all the acquired properties. Common Stock Offering On October 28, 2016, the Company completed a public offering of 6.0 million shares of its common stock at a price of $37.32 per share, for proceeds of $223.9 million , net of underwriting discounts. The Company used the net proceeds from the common stock offering to repay borrowings under the revolving credit facility and intends to use any remaining proceeds to fund a portion of the purchase price of the Sanchez Acquisition due on the closing date. Fall 2016 Borrowing Base Redetermination On October 24, 2016, as a result of the Fall 2016 borrowing base redetermination, the borrowing base was reaffirmed at $600.0 million until the next redetermination thereof. The borrowing base under the credit agreement is subject to regular redeterminations in the Spring and Fall of each year, as well as special redeterminations described in the credit agreement, in each case which may reduce the amount of the borrowing base. Hedging Update In October 2016, the Company entered into the following crude oil and natural gas derivative positions: Period Type of Contract Volumes (in Bbls/d) Weighted Average Floor Price ($/Bbl) Q3 2017 Fixed Price Swaps 6,000 $54.15 Q4 2017 Fixed Price Swaps 3,000 $55.01 Period Type of Contract Volumes (in MMBtu/d) Weighted Average Floor Price ($/MMBtu) FY 2017 Fixed Price Swaps 20,000 $3.30

Summary Of Significant Accoun19

Summary Of Significant Accounting Policies (Policy)	9 Months Ended
	Sep. 30, 2016
Accounting Policies [Abstract]
New Accounting Pronouncements	Recently Adopted Accounting Pronouncements In November 2015, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update (“ASU”) 2015-17, Balance Sheet Classification of Deferred Taxes (“ASU 2015-17”). ASU 2015-17 requires that all deferred tax liabilities and assets, as well as any related valuation allowance, be classified in the balance sheet as noncurrent. Effective January 1, 2016, the Company early adopted ASU 2015-17 which was applied prospectively and therefore the adoption had no impact on the consolidated balance sheet as of December 31, 2015. In April 2015, the FASB issued ASU 2015-03, Simplifying the Presentation of Debt Issuance Costs (“ASU 2015-03”). ASU 2015-03 is to simplify the presentation of debt issuance costs in financial statements by presenting such costs in the balance sheet as a direct deduction from the related debt rather than as an asset. In August 2015, the FASB issued ASU 2015-15, Interest-Imputation of Interest (Subtopic 835-30) (“ASU 2015-15”), which allows debt issuance costs associated with line-of-credit agreements to be deferred and presented as an asset in the balance sheet, subsequently amortizing the deferred debt issuance costs ratably over the term of the line-of-credit arrangement, regardless of whether there are any outstanding borrowings. Effective January 1, 2016, the Company adopted ASU 2015-03 and ASU 2015-15 and reclassified $19.7 million of unamortized debt issuance costs related to the Company’s senior notes from long-term assets to long-term debt in the consolidated balance sheet as of December 31, 2015. Debt issuance costs associated with the Company’s revolving credit facility remain classified as a long-term asset in the consolidated balance sheets. Recently Issued Accounting Pronouncements In August 2016, the FASB issued ASU No. 2016-15, Statement of Cash Flows (Topic 230) (“ASU 2016-15”), which is intended to reduce diversity in practice in how certain transactions are classified in the statement of cash flows. The guidance addresses eight specific cash flow issues for which current GAAP is either unclear or does not include specific guidance. ASU 2016-15 is effective for interim and annual periods beginning after December 15, 2017, with early adoption permitted, provided that it is adopted in its entirety in the same period. The Company is evaluating ASU 2016-15 to determine what impact adoption of the new standard will have on its consolidated statements of cash flows. In March 2016, the FASB issued ASU No. 2016-09, Compensation - Stock Compensation (Topic 718): Improvements to Employee Share-Based Payment Accounting (“ASU 2016-09”), which amends certain aspects of accounting for share-based payment arrangements. ASU 2016-09 revises or provides alternative accounting for the tax impacts of share-based payment arrangements, forfeitures, minimum statutory tax withholdings, and prescribes certain disclosures to be made in the period of adoption. ASU 2016-09 is effective for interim and annual periods beginning after December 15, 2016, with early adoption permitted. The Company is evaluating ASU 2016-09 to determine what impact adoption of the new standard will have on its consolidated financial statements and related disclosures. In February 2016, the FASB issued ASU No. 2016-02, Leases (Topic 842) (“ASU 2016-02”), which significantly changes accounting for leases by requiring that lessees recognize a right-of-use asset and a related lease liability representing the obligation to make lease payments, for virtually all lease transactions. Additional disclosures about an entity’s lease transactions will also be required. ASU 2016-02 defines a lease as “a contract, or part of a contract, that conveys the right to control the use of identified property, plant or equipment (an identified asset) for a period of time in exchange for consideration.” ASU 2016-02 is effective for interim and annual periods beginning after December 15, 2018 with early adoption permitted. Lessees and lessors are required to recognize and measure leases at the beginning of the earliest period presented in the financial statements using a modified retrospective approach. The Company is evaluating ASU 2016-02 to determine what impact adoption of the new standard will have on its consolidated financial statements and related disclosures. In May 2014, the FASB issued ASU No. 2014-09, Revenue From Contracts With Customers (Topic 606) (“ASU 2014-09”), which will require entities to recognize revenue to depict the transfer of promised goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods or services. ASU 2014-09 will supersede most current guidance related to revenue recognition when it becomes effective. The new standard also will require expanded disclosures regarding the nature, timing, amount and certainty of revenue and cash flows from contracts with customers. ASU 2014-09 is effective for interim and annual periods beginning after December 15, 2017 with early adoption permitted for interim and annual periods beginning after December 31, 2016. Companies are permitted to adopt ASU 2014-09 through the use of either the full retrospective approach or a modified retrospective approach. The Company does not currently intend to early-adopt ASU 2014-09 and has not determined which transition method it will use. The Company is evaluating ASU 2014-09 to determine what impact adoption of the new standard will have on its consolidated financial statements and related disclosures.

Property and Equipment, Net (Ta

Property and Equipment, Net (Tables)	9 Months Ended
	Sep. 30, 2016
Property, Plant and Equipment [Abstract]
Schedule of Property and Equipment	As of September 30, 2016 and December 31, 2015 , total property and equipment, net consisted of the following: September 30, December 31, (In thousands) Proved properties $4,467,760 $3,976,511 Accumulated depreciation, depletion and amortization and impairments (3,340,496 ) (2,607,360 ) Proved properties, net 1,127,264 1,369,151 Unproved properties, not being amortized Unevaluated leasehold and seismic costs 163,915 280,263 Exploratory wells in progress 2,051 9,432 Capitalized interest 30,772 45,757 Total unproved properties, not being amortized 196,738 335,452 Other property and equipment 23,106 22,677 Accumulated depreciation (12,413 ) (10,419 ) Other property and equipment, net 10,693 12,258 Total property and equipment, net $1,334,695 $1,716,861
Schedule of Impairment of Oil and Gas Properties	Three Months Ended Nine Months Ended 2016 2015 2016 2015 Impairment of proved oil and gas properties (in thousands) $105,057 $812,752 $576,540 $812,752 End of period price ($/Bbl) $38.36 $56.05 $38.36 $56.05 Beginning of period price ($/Bbl) $39.84 $68.92 $47.24 $92.24 Percent decrease in price (4 %) (19 %) (19 %) (39 %)

Income Taxes (Tables)

Income Taxes (Tables)	9 Months Ended
	Sep. 30, 2016
Income Tax Disclosure [Abstract]
Schedule Of Effective Income Tax Rate Reconciliation	The Company’s income tax benefit from continuing operations differs from the income tax benefit computed by applying the U.S. federal statutory corporate income tax rate of 35% to loss from continuing operations before income taxes as follows: Three Months Ended Nine Months Ended 2016 2015 2016 2015 (In thousands) Loss from continuing operations before income taxes ($101,487 ) ($811,683 ) ($674,695 ) ($917,670 ) Income tax benefit at the statutory rate 35,520 284,089 236,143 321,185 State income tax benefit, net of U.S. federal income taxes 575 6,542 3,859 6,321 Deferred tax assets valuation allowance (36,696 ) (187,607 ) (240,897 ) (187,607 ) Texas Franchise Tax rate reduction, net of U.S. federal income taxes — — — 1,671 Other 914 (109 ) 895 (1,114 ) Income tax benefit from continuing operations $313 $102,915 $— $140,456

Long-Term Debt (Tables)

Long-Term Debt (Tables)	9 Months Ended
	Sep. 30, 2016
Debt Disclosure [Abstract]
Schedule of Long-term Debt Instruments	Long-term debt consisted of the following as of September 30, 2016 and December 31, 2015 : September 30, December 31, (In thousands) Senior Secured Revolving Credit Facility due 2018 $96,000 $— 7.50% Senior Notes due 2020 600,000 600,000 Unamortized premium for 7.50% Senior Notes 1,080 1,251 Unamortized debt issuance costs for 7.50% Senior Notes (7,950 ) (9,048 ) 6.25% Senior Notes due 2023 650,000 650,000 Unamortized debt issuance costs for 6.25% Senior Notes (9,754 ) (10,611 ) Other long-term debt due 2028 4,425 4,425 Long-term debt $1,333,801 $1,236,017
Interest and Commitment Fee Rates	The Company also incurs commitment fees as set forth in the table below based on the unused portion of lender commitments, which are included in interest expense, net. Ratio of Outstanding Borrowings and Letters of Credit to Lender Commitments Applicable Margin for Base Rate Loans Applicable Margin for Eurodollar Loans Commitment Fee Less than 25% 1.00% 2.00% 0.500% Greater than or equal to 25% but less than 50% 1.25% 2.25% 0.500% Greater than or equal to 50% but less than 75% 1.50% 2.50% 0.500% Greater than or equal to 75% but less than 90% 1.75% 2.75% 0.500% Greater than or equal to 90% 2.00% 3.00% 0.500%

Stock-Based Compensation (Table

Stock-Based Compensation (Tables)	9 Months Ended
	Sep. 30, 2016
Schedule of Share-Based Compensation Expense [Abstract]
Schedule of Employee Service Share-based Compensation, Allocation of Recognized Period Costs	The Company recognized the following stock-based compensation expense (benefit), net for the periods indicated which is reflected as “General and administrative, net” in the consolidated statements of operations: Three Months Ended Nine Months Ended 2016 2015 2016 2015 (In thousands) Restricted stock awards and units $5,487 $6,013 $23,079 $17,242 Stock appreciation rights 3,361 (11,557 ) 9,581 (5,666 ) Performance share awards 722 598 2,052 1,363 9,570 (4,946 ) 34,712 12,939 Less: amounts capitalized to oil and gas properties (1,150 ) (647 ) (3,878 ) (3,736 ) Total stock-based compensation expense (benefit), net $8,420 ($5,593 ) $30,834 $9,203 Income tax benefit (expense) at the U.S. federal statutory rate $2,947 ($1,958 ) $10,792 $3,221

Earnings Per Share (Tables)

Earnings Per Share (Tables)	9 Months Ended
	Sep. 30, 2016
Schedule of Earnings Per Share [Abstract]
Schedule Of Supplemental Net Income Per Common Share	Supplemental loss from continuing operations per common share information is provided below: Three Months Ended Nine Months Ended 2016 2015 2016 2015 (In thousands, except per share amounts) Loss from Continuing Operations ($101,174 ) ($708,768 ) ($674,695 ) ($777,214 ) Basic weighted average common shares outstanding 58,945 51,543 58,705 49,742 Effect of dilutive instruments — — — — Diluted weighted average common shares outstanding 58,945 51,543 58,705 49,742 Loss from Continuing Operations Per Common Share Basic ($1.72 ) ($13.75 ) ($11.49 ) ($15.62 ) Diluted ($1.72 ) ($13.75 ) ($11.49 ) ($15.62 )

Derivative Instruments (Tables)

Derivative Instruments (Tables)	9 Months Ended
	Sep. 30, 2016
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Schedule of Derivative Instruments	The following sets forth a summary of the Company’s open natural gas derivative positions at average NYMEX prices as of September 30, 2016 : Period Type of Contract Natural Gas Volumes Weighted FY 2017 Sold Call Options 33,000 $3.00 FY 2018 Sold Call Options 33,000 $3.25 FY 2019 Sold Call Options 33,000 $3.25 FY 2020 Sold Call Options 33,000 $3.50 The following sets forth a summary of the Company’s open crude oil derivative positions at average NYMEX prices as of September 30, 2016 : Period Type of Contract Crude Oil Volumes (in Bbls/d) Weighted Average Floor Price ($/Bbl) Weighted Average Ceiling Price ($/Bbl) Q4 2016 Fixed Price Swaps 9,750 $60.03 Q4 2016 Costless Collars 4,000 $50.00 $76.50 Q1 2017 Fixed Price Swaps 12,000 $50.13 Q2 2017 Fixed Price Swaps 12,000 $50.13 FY 2018 Sold Call Options 2,488 $60.00 FY 2018 Net Sold Call Options 900 $75.00 FY 2019 Sold Call Options 2,975 $62.50 FY 2019 Net Sold Call Options 900 $77.50 FY 2020 Sold Call Options 3,675 $65.00 FY 2020 Net Sold Call Options 900 $80.00 In October 2016, the Company entered into the following crude oil and natural gas derivative positions: Period Type of Contract Volumes (in Bbls/d) Weighted Average Floor Price ($/Bbl) Q3 2017 Fixed Price Swaps 6,000 $54.15 Q4 2017 Fixed Price Swaps 3,000 $55.01 Period Type of Contract Volumes (in MMBtu/d) Weighted Average Floor Price ($/MMBtu) FY 2017 Fixed Price Swaps 20,000 $3.30
Schedule of Concentration of Risk	Counterparty September 30, 2016 December 31, 2015 Regions 40 % 9 % Wells Fargo 34 % 35 % Union Bank 26 % 5 % Capital One — % 1 % Societe Generale — % 37 % Citibank — % 13 % Total 100 % 100 %

Fair Value Measurements (Tables

Fair Value Measurements (Tables)	9 Months Ended
	Sep. 30, 2016
Fair Value Disclosures [Abstract]
Offsetting Assets	The following tables summarize the Company’s assets and liabilities measured at fair value on a recurring basis as presented in the consolidated balance sheets as of September 30, 2016 and December 31, 2015 . All items included in the tables below are Level 2 inputs within the fair value hierarchy: September 30, 2016 Gross Amounts Recognized Gross Amounts Offset in the Consolidated Balance Sheets Net Amounts Presented in the Consolidated Balance Sheets (In thousands) Derivative assets Derivative assets-current $31,742 ($11,596 ) $20,146 Derivative assets-non current 1,992 (1,992 ) — Derivative liabilities Other current liabilities (11,596 ) 11,596 — Derivative liabilities-non current (31,346 ) 1,992 (29,354 ) Total ($9,208 ) $— ($9,208 ) December 31, 2015 Gross Amounts Recognized Gross Amounts Offset in the Consolidated Balance Sheets Net Amounts Presented in the Consolidated Balance Sheets (In thousands) Derivative assets Derivative assets-current $159,447 ($28,347 ) $131,100 Derivative assets-non current 10,780 (9,665 ) 1,115 Derivative liabilities Other current liabilities (28,364 ) 28,347 (17 ) Derivative liabilities-non current (22,313 ) 9,665 (12,648 ) Total $119,550 $— $119,550
Schedule of Carrying Value and Estimated Fair Value of Debt Instruments	The following table presents the carrying amounts of the Company’s senior notes and other long-term debt, net of debt premiums and debt issuance costs, with the fair values of each based on quoted market prices. September 30, 2016 December 31, 2015 Carrying Amount Fair Value Carrying Amount Fair Value (In thousands) 7.50% Senior Notes due 2020 $593,130 $615,000 $592,203 $528,000 6.25% Senior Notes due 2023 640,246 643,500 639,389 533,000 Other long-term debt due 2028 4,425 4,337 4,425 4,182

Condensed Consolidating Finan27

Condensed Consolidating Financial Information (Tables)	9 Months Ended
	Sep. 30, 2016
Condensed Consolidating Financial Information [Abstract]
Schedule Of Condensed Consolidating Balance Sheets	CARRIZO OIL & GAS, INC. CONDENSED CONSOLIDATING BALANCE SHEETS (In thousands) (Unaudited) September 30, 2016 Parent Company Combined Guarantor Subsidiaries Combined Non- Guarantor Subsidiaries Eliminations Consolidated Assets Total current assets $2,551,367 $50,479 $— ($2,524,333 ) $77,513 Total property and equipment, net 42,759 1,291,991 3,800 (3,855 ) 1,334,695 Investment in subsidiaries (1,338,051 ) — — 1,338,051 — Other assets 8,143 156 — — 8,299 Total Assets $1,264,218 $1,342,626 $3,800 ($1,190,137 ) $1,420,507 Liabilities and Shareholders’ Deficit Current liabilities $94,952 $2,658,363 $3,800 ($2,527,353 ) $229,762 Long-term liabilities 1,357,911 22,314 — 15,879 1,396,104 Total shareholders’ deficit (188,645 ) (1,338,051 ) — 1,321,337 (205,359 ) Total Liabilities and Shareholders’ Deficit $1,264,218 $1,342,626 $3,800 ($1,190,137 ) $1,420,507 December 31, 2015 Parent Company Combined Guarantor Subsidiaries Combined Non- Guarantor Subsidiaries Eliminations Consolidated Assets Total current assets $2,578,034 $52,067 $— ($2,397,919 ) $232,182 Total property and equipment, net 44,499 1,671,774 3,059 (2,471 ) 1,716,861 Investment in subsidiaries (815,836 ) — — 815,836 — Other assets 74,679 156 — (16,632 ) 58,203 Total Assets $1,881,376 $1,723,997 $3,059 ($1,601,186 ) $2,007,246 Liabilities and Shareholders’ Equity Current liabilities $161,792 $2,521,572 $3,059 ($2,400,939 ) $285,484 Long-term liabilities 1,260,200 18,261 — (753 ) 1,277,708 Total shareholders’ equity 459,384 (815,836 ) — 800,506 444,054 Total Liabilities and Shareholders’ Equity $1,881,376 $1,723,997 $3,059 ($1,601,186 ) $2,007,246
Schedule Of Condensed Consolidating Statements Of Operations	CARRIZO OIL & GAS, INC. CONDENSED CONSOLIDATING STATEMENTS OF OPERATIONS (In thousands) (Unaudited) Three Months Ended September 30, 2016 Parent Company Combined Guarantor Subsidiaries Combined Non- Guarantor Subsidiaries Eliminations Consolidated Total revenues $105 $111,072 $— $— $111,177 Total costs and expenses 28,551 184,047 — 66 212,664 Loss from continuing operations before income taxes (28,446 ) (72,975 ) — (66 ) (101,487 ) Income tax benefit — — — 313 313 Equity in loss of subsidiaries (72,975 ) — — 72,975 — Loss from continuing operations (101,421 ) (72,975 ) — 73,222 (101,174 ) Income from discontinued operations, net of income taxes — — — — — Net loss ($101,421 ) ($72,975 ) $— $73,222 ($101,174 ) Three Months Ended September 30, 2015 Parent Company Combined Guarantor Subsidiaries Combined Non- Guarantor Subsidiaries Eliminations Consolidated Total revenues $235 $106,002 $— $— $106,237 Total costs and expenses (6,718 ) 890,350 — 34,288 917,920 Income (loss) from continuing operations before income taxes 6,953 (784,348 ) — (34,288 ) (811,683 ) Income tax (expense) benefit (25,496 ) 119,847 — 8,564 102,915 Equity in loss of subsidiaries (664,501 ) — — 664,501 — Loss from continuing operations (683,044 ) (664,501 ) — 638,777 (708,768 ) Income from discontinued operations, net of income taxes 1,121 — — — 1,121 Net loss ($681,923 ) ($664,501 ) $— $638,777 ($707,647 ) CARRIZO OIL & GAS, INC. CONDENSED CONSOLIDATING STATEMENTS OF OPERATIONS (In thousands) (Unaudited) Nine Months Ended September 30, 2016 Parent Company Combined Guarantor Subsidiaries Combined Non- Guarantor Subsidiaries Eliminations Consolidated Total revenues $349 $299,414 $— $— $299,763 Total costs and expenses 151,445 822,582 — 431 974,458 Loss from continuing operations before income taxes (151,096 ) (523,168 ) — (431 ) (674,695 ) Income tax benefit — — — — — Equity in loss of subsidiaries (523,168 ) — — 523,168 — Loss from continuing operations (674,264 ) (523,168 ) — 522,737 (674,695 ) Income from discontinued operations, net of income taxes — — — — — Net loss ($674,264 ) ($523,168 ) $— $522,737 ($674,695 ) Nine Months Ended September 30, 2015 Parent Company Combined Guarantor Subsidiaries Combined Non- Guarantor Subsidiaries Eliminations Consolidated Total revenues $1,485 $328,296 $— $— $329,781 Total costs and expenses 116,793 1,101,671 — 28,987 1,247,451 Loss from continuing operations before (115,308 ) (773,375 ) — (28,987 ) (917,670 ) Income tax benefit 17,296 116,006 — 7,154 140,456 Equity in loss of subsidiaries (657,369 ) — — 657,369 — Loss from continuing operations (755,381 ) (657,369 ) — 635,536 (777,214 ) Income from discontinued operations, net of income taxes 2,225 — — — 2,225 Net loss ($753,156 ) ($657,369 ) $— $635,536 ($774,989 )
Schedule Of Condensed Consolidating Statements Of Cash Flows	CARRIZO OIL & GAS, INC. CONDENSED CONSOLIDATING STATEMENTS OF CASH FLOWS (In thousands) (Unaudited) Nine Months Ended September 30, 2016 Parent Company Combined Guarantor Subsidiaries Combined Non- Guarantor Subsidiaries Eliminations Consolidated Net cash provided by (used in) operating activities from continuing operations ($10,882 ) $208,729 $— $— $197,847 Net cash used in investing activities from continuing operations (122,846 ) (331,351 ) (740 ) 123,362 (331,575 ) Net cash provided by financing activities from 94,045 122,622 740 (123,362 ) 94,045 Net cash used in discontinued operations — — — — — Net decrease in cash and cash equivalents (39,683 ) — — — (39,683 ) Cash and cash equivalents, beginning of period 42,918 — — — 42,918 Cash and cash equivalents, end of period $3,235 $— $— $— $3,235 Nine Months Ended September 30, 2015 Parent Company Combined Guarantor Subsidiaries Combined Non- Guarantor Subsidiaries Eliminations Consolidated Net cash provided by (used in) operating activities from continuing operations ($8,817 ) $293,036 $— $— $284,219 Net cash used in investing activities from (396,036 ) (529,046 ) — 386,010 (539,072 ) Net cash provided by financing activities from continuing operations 399,391 236,010 — (386,010 ) 249,391 Net cash used in discontinued operations (3,372 ) — — — (3,372 ) Net decrease in cash and cash equivalents (8,834 ) — — — (8,834 ) Cash and cash equivalents, beginning of period 10,838 — — — 10,838 Cash and cash equivalents, end of period $2,004 $— $— $— $2,004

Supplemental Cash Flow Inform28

Supplemental Cash Flow Information (Tables)	9 Months Ended
	Sep. 30, 2016
Supplemental Cash Flow Elements [Abstract]
Schedule of Cash Flow, Supplemental Disclosures	Supplemental disclosures to the consolidated statements of cash flows are presented below: Nine Months Ended 2016 2015 (In thousands) Non-cash investing activities: Increase (decrease) in capital expenditure payables and accruals $7,316 ($71,967 ) Other non-cash investing activities (1) 12,468 23,737

Subsequent Events (Tables)

Subsequent Events (Tables)	9 Months Ended
	Sep. 30, 2016
Subsequent Events, Derivative Instruments (Schedule of Natural Gas Derivatives) [Abstract]
Schedule of Derivative Instruments	The following sets forth a summary of the Company’s open natural gas derivative positions at average NYMEX prices as of September 30, 2016 : Period Type of Contract Natural Gas Volumes Weighted FY 2017 Sold Call Options 33,000 $3.00 FY 2018 Sold Call Options 33,000 $3.25 FY 2019 Sold Call Options 33,000 $3.25 FY 2020 Sold Call Options 33,000 $3.50 The following sets forth a summary of the Company’s open crude oil derivative positions at average NYMEX prices as of September 30, 2016 : Period Type of Contract Crude Oil Volumes (in Bbls/d) Weighted Average Floor Price ($/Bbl) Weighted Average Ceiling Price ($/Bbl) Q4 2016 Fixed Price Swaps 9,750 $60.03 Q4 2016 Costless Collars 4,000 $50.00 $76.50 Q1 2017 Fixed Price Swaps 12,000 $50.13 Q2 2017 Fixed Price Swaps 12,000 $50.13 FY 2018 Sold Call Options 2,488 $60.00 FY 2018 Net Sold Call Options 900 $75.00 FY 2019 Sold Call Options 2,975 $62.50 FY 2019 Net Sold Call Options 900 $77.50 FY 2020 Sold Call Options 3,675 $65.00 FY 2020 Net Sold Call Options 900 $80.00 In October 2016, the Company entered into the following crude oil and natural gas derivative positions: Period Type of Contract Volumes (in Bbls/d) Weighted Average Floor Price ($/Bbl) Q3 2017 Fixed Price Swaps 6,000 $54.15 Q4 2017 Fixed Price Swaps 3,000 $55.01 Period Type of Contract Volumes (in MMBtu/d) Weighted Average Floor Price ($/MMBtu) FY 2017 Fixed Price Swaps 20,000 $3.30

Summary Of Significant Accoun30

Summary Of Significant Accounting Policies (Narrative) (Details) $ in Millions	Dec. 31, 2015USD ($)
Senior Notes [Member]
Summary Of Significant Accounting Policies [Line Items]
Unamortized Debt Issuance Expense	$ 19.7

Property and Equipment, Net (Na

Property and Equipment, Net (Narrative) (Details) $ in Thousands	3 Months Ended			9 Months Ended
	Dec. 31, 2016USD ($)$ / bbls	Sep. 30, 2016USD ($)$ / bbls$ / Boe	Sep. 30, 2015USD ($)$ / bbls$ / Boe	Sep. 30, 2016USD ($)$ / bbls$ / Boe	Sep. 30, 2015USD ($)$ / bbls$ / Boe	Jun. 30, 2016$ / bbls	Dec. 31, 2015$ / bbls	Jun. 30, 2015$ / bbls	Dec. 31, 2014$ / bbls
Property, Plant and Equipment [Line Items]
Average depreciation, depletion and amortization, per Boe | $ / Boe		12.72	24.19	13.79	23.82
Internal costs capitalized, Oil and Gas producing activities		$ 2,700	$ 3,100	$ 8,500	$ 14,000
Capitalized interest		2,900	7,500	$ 13,400	26,200
Reserves discount factor				10.00%
Impairment of oil and gas properties, net of taxes		105,100	729,300	$ 576,500	729,300
Impairment of proved oil and gas properties		$ 105,057	$ 812,752	$ 576,540	$ 812,752
Change in price used in ceiling test calculation		(4.00%)	(19.00%)	(19.00%)	(39.00%)
Price to calculate ceiling test impairment | $ / bbls						39.84	47.24
Scenario, Forecast [Member]
Property, Plant and Equipment [Line Items]
Impairment of proved oil and gas properties	$ 50,000
Change in price used in ceiling test calculation	4.00%
Crude Oil [Member]
Property, Plant and Equipment [Line Items]
Average Realized Price | $ / bbls		38.36	56.05	38.36	56.05	39.84	47.24	68.92	92.24
Crude Oil [Member] | Scenario, Forecast [Member]
Property, Plant and Equipment [Line Items]
Average Realized Price | $ / bbls	39.26

Property and Equipment, Net (Sc

Property and Equipment, Net (Schedule of Property and Equipment) (Details) - USD ($) $ in Thousands	Sep. 30, 2016	Dec. 31, 2015
Property, Plant and Equipment [Abstract]
Proved properties	$ 4,467,760	$ 3,976,511
Accumulated depreciation, depletion and amortization and impairments	(3,340,496)	(2,607,360)
Proved properties, net	1,127,264	1,369,151
Unproved properties, not being amortized
Unevaluated leasehold and seismic costs	163,915	280,263
Exploratory wells in progress	2,051	9,432
Capitalized interest	30,772	45,757
Total unproved properties, not being amortized	196,738	335,452
Other property and equipment	23,106	22,677
Accumulated depreciation	(12,413)	(10,419)
Other property and equipment, net	10,693	12,258
Total property and equipment, net	$ 1,334,695	$ 1,716,861

Property and Equipment, Net (33

Property and Equipment, Net (Schedule of Impairment of Oil and Gas Properties) (Details) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2016USD ($)$ / bbls	Sep. 30, 2015USD ($)$ / bbls	Sep. 30, 2016USD ($)$ / bbls	Sep. 30, 2015USD ($)$ / bbls	Jun. 30, 2016$ / bbls	Dec. 31, 2015$ / bbls	Jun. 30, 2015$ / bbls	Dec. 31, 2014$ / bbls
Impairment of Oil and Gas Properties [Line Items]
Impairment of proved oil and gas properties | $	$ 105,057	$ 812,752	$ 576,540	$ 812,752
Change in price used in ceiling test calculation	(4.00%)	(19.00%)	(19.00%)	(39.00%)
Crude Oil [Member]
Impairment of Oil and Gas Properties [Line Items]
Average Realized Price | $ / bbls	38.36	56.05	38.36	56.05	39.84	47.24	68.92	92.24

Income Taxes (Narrative) (Detai

Income Taxes (Narrative) (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015
Income Taxes [Line Items]
U.S. federal statutory corporate pretax rate			35.00%
Deferred Tax Assets, Valuation Allowance	$ 36,696	$ 187,607	$ 240,897	$ 187,607
Deferred Tax Assets, Net	$ 0		$ 0

Income Taxes (Schedule Of Effec

Income Taxes (Schedule Of Effective Income Tax Rate Reconciliation) (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015
Income Tax Disclosure [Abstract]
Loss from continuing operations before income taxes	$ (101,487)	$ (811,683)	$ (674,695)	$ (917,670)
Income tax benefit at the statutory rate	35,520	284,089	236,143	321,185
State income tax benefit, net of U.S. federal income taxes	575	6,542	3,859	6,321
Deferred tax assets valuation allowance	(36,696)	(187,607)	(240,897)	(187,607)
Texas Franchise Tax rate reduction, net of U.S. federal income taxes	0	0	0	1,671
Other	914	(109)	895	(1,114)
Income tax benefit from continuing operations	$ 313	$ 102,915	$ 0	$ 140,456

Long-Term Debt (Narrative) (Det

Long-Term Debt (Narrative) (Details)	2 Months Ended	3 Months Ended	9 Months Ended
	Jun. 30, 2016Rate	Mar. 31, 2016USD ($)Rate	Sep. 30, 2016USD ($)Rate	Oct. 24, 2016USD ($)	May 03, 2016USD ($)	Dec. 31, 2015USD ($)
Senior Secured Revolving Credit Facility [Member]
Debt Instrument [Line Items]
Line of credit facility, current borrowing capacity		$ 685,000,000	$ 600,000,000
Line of credit facility amount outstanding			$ 96,000,000			$ 0
Debt, Weighted Average Interest Rate			2.46%
Letters of credit outstanding amount			$ 415,000
Ratio of Total Secured Debt to EBITDA			0.24
Ratio of EBITDA to Interest Expense			4.35
Pre-Tax SEC PV10 Reserve Value Percentage | Rate	90.00%	80.00%	90.00%
Line of Credit Facility, Availability of Issuances of Additional Senior Notes					$ 400,000,000
Consolidated Cash Balance Threshold					$ 50,000,000
Credit Facility Availability Threshold					20.00%
Increase to Margin for Base Rate and Eurodollar Loans					0.50%
Utilization of lender commitments	50.00%
Federal funds rate plus percentage			0.50%
Adjusted LIBO rate plus percentage			1.00%
Current Ratio			2.63
Senior Secured Revolving Credit Facility [Member] | Maximum [Member]
Debt Instrument [Line Items]
Ratio of Total Secured Debt to EBITDA			2		2
Ratio of Total Debt to EBITDA					3.50
Senior Secured Revolving Credit Facility [Member] | Minimum [Member]
Debt Instrument [Line Items]
Ratio of EBITDA to Interest Expense			2.50		2.50
Current Ratio			1
6.25% Senior Notes [Member]
Debt Instrument [Line Items]
Long term debt			$ 650,000,000			650,000,000
7.50% Senior Notes [Member]
Debt Instrument [Line Items]
Long term debt			$ 600,000,000			$ 600,000,000
Subsequent Event [Member] | Senior Secured Revolving Credit Facility [Member]
Debt Instrument [Line Items]
Line of credit facility, current borrowing capacity				$ 600,000,000
Less than 50 percent [Member] | Senior Secured Revolving Credit Facility [Member]
Debt Instrument [Line Items]
Line of Credit Facility, Commitment Fee Percentage	0.50%	0.375%

Long-Term Debt (Schedule of Lon

Long-Term Debt (Schedule of Long-Term Debt) (Details) - USD ($) $ in Thousands	Sep. 30, 2016	Dec. 31, 2015
Debt Instrument [Line Items]
Long-term debt	$ 1,333,801	$ 1,236,017
Senior Secured Revolving Credit Facility [Member]
Debt Instrument [Line Items]
Line of credit facility amount outstanding	96,000	0
7.50% Senior Notes [Member]
Debt Instrument [Line Items]
Long term debt	600,000	600,000
Debt instrument, unamortized premium	1,080	1,251
Unamortized Debt Issuance Expense	(7,950)	(9,048)
6.25% Senior Notes [Member]
Debt Instrument [Line Items]
Long term debt	650,000	650,000
Unamortized Debt Issuance Expense	(9,754)	(10,611)
Other Long Term Debt [Member]
Debt Instrument [Line Items]
Long term debt	$ 4,425	$ 4,425

Long-Term Debt (Interest and Co

Long-Term Debt (Interest and Commitment Fee Rates) (Details)	9 Months Ended
	Sep. 30, 2016
Less than 25 percent [Member]
Interest and Commitment Fee Rates [Line Items]
Margin for base rate loans	1.00%
Margin for eurodollar loans	2.00%
Line of Credit Facility, Commitment Fee Percentage	0.50%
Greater than or equal to 25 percent but less than 50 percent [Member]
Interest and Commitment Fee Rates [Line Items]
Margin for base rate loans	1.25%
Margin for eurodollar loans	2.25%
Line of Credit Facility, Commitment Fee Percentage	0.50%
Greater than or equal to 50 percent but less than 75 percent [Member]
Interest and Commitment Fee Rates [Line Items]
Margin for base rate loans	1.50%
Margin for eurodollar loans	2.50%
Line of Credit Facility, Commitment Fee Percentage	0.50%
Greater than or equal to 75 percent but less than 90 percent [Member]
Interest and Commitment Fee Rates [Line Items]
Margin for base rate loans	1.75%
Margin for eurodollar loans	2.75%
Line of Credit Facility, Commitment Fee Percentage	0.50%
Greater than or equal to 90 percent [Member]
Interest and Commitment Fee Rates [Line Items]
Margin for base rate loans	2.00%
Margin for eurodollar loans	3.00%
Line of Credit Facility, Commitment Fee Percentage	0.50%

Stock-Based Compensation (Sched

Stock-Based Compensation (Schedule of Share-Based Compensation Expense) (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015
Share-based Compensation Arrangement by Share-based Payment Award, Compensation Cost [Line Items]
Allocated Share-based Compensation Expense	$ 9,570	$ (4,946)	$ 34,712	$ 12,939
Less: amounts capitalized	(1,150)	(647)	(3,878)	(3,736)
Share-based Compensation Arrangement by Share-based Payment Award, Compensation Cost	8,420	(5,593)	30,834	9,203
Income tax benefit	2,947	(1,958)	10,792	3,221
Restricted Stock Awards And Units [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Compensation Cost [Line Items]
Allocated Share-based Compensation Expense	5,487	6,013	23,079	17,242
Stock Appreciation Rights (SARs) [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Compensation Cost [Line Items]
Allocated Share-based Compensation Expense	3,361	(11,557)	9,581	(5,666)
Performance Shares [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Compensation Cost [Line Items]
Allocated Share-based Compensation Expense	$ 722	$ 598	$ 2,052	$ 1,363

Earnings Per Share (Narrative)

Earnings Per Share (Narrative) (Details) - shares	3 Months Ended		9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015
Earnings Per Share [Abstract]
Antidilutive Securities Excluded from Computation of Earnings Per Share, Amount	697,829	421,978	663,831	663,383

Earnings Per Share (Schedule of

Earnings Per Share (Schedule of Supplemental Earnings Per Common Share) (Details) - USD ($) $ / shares in Units, shares in Thousands, $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015
Earnings Per Share [Abstract]
Net income (loss) from continuing operations	$ (101,174)	$ (708,768)	$ (674,695)	$ (777,214)
Basic weighted average common shares outstanding	58,945	51,543	58,705	49,742
Effect of dilutive instruments	0	0	0	0
Diluted weighted average common shares outstanding	58,945	51,543	58,705	49,742
Income (Loss) from Continuing Operations Per Common Share
Income (loss) from continuing operations - basic (in dollars per share)	$ (1.72)	$ (13.75)	$ (11.49)	$ (15.62)
Income (loss) from continuing operations - diluted (in dollars per share)	$ (1.72)	$ (13.75)	$ (11.49)	$ (15.62)

Derivative Instruments (Narrati

Derivative Instruments (Narrative) (Details) $ in Thousands	3 Months Ended						9 Months Ended
	Mar. 31, 2017USD ($)	Dec. 31, 2016USD ($)	Sep. 30, 2016USD ($)	Jun. 30, 2016USD ($)	Mar. 31, 2016USD ($)	Sep. 30, 2015USD ($)	Sep. 30, 2016USD ($)	Sep. 30, 2015USD ($)	Mar. 07, 2016bbl / d$ / bbls	Feb. 17, 2016bbl / d$ / bbls	Dec. 31, 2015USD ($)	Feb. 11, 2015USD ($)
Derivative [Line Items]
Value of Offsetting Derivative Transactions			$ 10,600				$ 10,600					$ 166,400
Gain Recognized on Offsetting Derivative Transaction			9,300			$ 40,000	36,900	$ 79,900
Derivative, Cost of Hedge Net of Cash Received			2,800	$ 2,800	$ 5,600
(Gain) loss on derivatives, net			(11,744)			$ (28,752)	29,938	$ (42,596)
Derivative Asset, Fair Value			$ 6,800				$ 6,800				$ 119,600
Derivative Positions, January through June Two Thousand Seventeen [Member] | Crude Oil [Member] | Swaps [Member]
Derivative [Line Items]
Weighted Average Floor Price ($/Bbls) | $ / bbls									50	50.27
Derivative, Nonmonetary Notional Amount | bbl / d									6,000	6,000
Scenario, Forecast [Member]
Derivative [Line Items]
Gain Recognized on Offsetting Derivative Transaction	$ 2,700	$ 7,900

Derivative Instruments (Schedul

Derivative Instruments (Schedule Of Crude Oil Derivative Positions) (Details) - Crude Oil [Member]	Sep. 30, 2016bbl / d$ / bbls
Energy Related Derivative, Weighted Average Floor Price of $60.03 [Member] | Swaps [Member] | Derivative Positions, Q4 2016
Derivative [Line Items]
Weighted Average Floor Price ($/Bbls)	60.03
Derivative, Nonmonetary Notional Amount | bbl / d	9,750
Energy Related Derivative, Weighted Average Floor Price of $50.00, Weighted Average Ceiling Price of $76.50 [Member] | Collars [Member] | Derivative Positions, Q4 2016
Derivative [Line Items]
Weighted Average Floor Price ($/Bbls)	50
Weighted Average Ceiling Price ($/Bbls)	76.50
Derivative, Nonmonetary Notional Amount | bbl / d	4,000
Energy Related Derivative, Weighted Average Floor Price of $50.13 [Member] | Swaps [Member] | Derivative Positions, Q1 2017
Derivative [Line Items]
Weighted Average Floor Price ($/Bbls)	50.13
Derivative, Nonmonetary Notional Amount | bbl / d	12,000
Energy Related Derivative, Weighted Average Floor Price of $50.13 [Member] | Swaps [Member] | Derivative Positions, Q2 2017
Derivative [Line Items]
Weighted Average Floor Price ($/Bbls)	50.13
Derivative, Nonmonetary Notional Amount | bbl / d	12,000
Energy Related Derivative, Weighted Average Ceiling Price of $60.00 [Member] | Call Option [Member] | Derivative Positions, 2018
Derivative [Line Items]
Weighted Average Ceiling Price ($/Bbls)	60
Derivative, Nonmonetary Notional Amount | bbl / d	2,488
Energy Related Derivative, Weighted Average Ceiling Price of $75.00 [Member] | Call Option [Member] | Derivative Positions, 2018
Derivative [Line Items]
Weighted Average Ceiling Price ($/Bbls)	75
Derivative, Nonmonetary Notional Amount | bbl / d	900
Energy Related Derivative, Weighted Average Ceiling Price of $62.50 [Member] | Call Option [Member] | Derivative Positions, 2019
Derivative [Line Items]
Weighted Average Ceiling Price ($/Bbls)	62.50
Derivative, Nonmonetary Notional Amount | bbl / d	2,975
Energy Related Derivative, Weighted Average Ceiling Price of $77.50 [Member] | Call Option [Member] | Derivative Positions, 2019
Derivative [Line Items]
Weighted Average Ceiling Price ($/Bbls)	77.50
Derivative, Nonmonetary Notional Amount | bbl / d	900
Energy Related Derivative, Weighted Average Ceiling Price of $65.00 [Member] | Call Option [Member] | Derivative Positions, 2020
Derivative [Line Items]
Weighted Average Ceiling Price ($/Bbls)	65
Derivative, Nonmonetary Notional Amount | bbl / d	3,675
Energy Related Derivative, Weighted Average Ceiling Price of $80.00 [Member] | Call Option [Member] | Derivative Positions, 2020
Derivative [Line Items]
Weighted Average Ceiling Price ($/Bbls)	80
Derivative, Nonmonetary Notional Amount | bbl / d	900

Derivative Instruments (Sched44

Derivative Instruments (Schedule Of Natural Gas Derivative Positions) (Details) - Call Option [Member] - Natural Gas Derivative Positions [Member]	Sep. 30, 2016MMBTU / d$ / MMBTU
Derivative Positions, 2017
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount | MMBTU / d	33,000
Weighted Average Ceiling Price ($/MMBtu) | $ / MMBTU	3
Derivative Positions, 2018
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount | MMBTU / d	33,000
Weighted Average Ceiling Price ($/MMBtu) | $ / MMBTU	3.25
Derivative Positions, 2019
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount | MMBTU / d	33,000
Weighted Average Ceiling Price ($/MMBtu) | $ / MMBTU	3.25
Derivative Positions, 2020
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount | MMBTU / d	33,000
Weighted Average Ceiling Price ($/MMBtu) | $ / MMBTU	3.50

Derivative Instruments (Sched45

Derivative Instruments (Schedule of Concentration Risk Percentage) (Details) - Derivative Credit Risk [Member]	9 Months Ended	12 Months Ended
	Sep. 30, 2016	Dec. 31, 2015
Concentration Risk [Line Items]
Concentration Risk, Percentage	100.00%	100.00%
Wells Fargo [Member]
Concentration Risk [Line Items]
Concentration Risk, Percentage	34.00%	35.00%
Regions [Member]
Concentration Risk [Line Items]
Concentration Risk, Percentage	40.00%	9.00%
Union Bank [Member]
Concentration Risk [Line Items]
Concentration Risk, Percentage	26.00%	5.00%
Capital One [Member]
Concentration Risk [Line Items]
Concentration Risk, Percentage	0.00%	1.00%
Societe Generale [Member]
Concentration Risk [Line Items]
Concentration Risk, Percentage	0.00%	37.00%
Citibank [Member]
Concentration Risk [Line Items]
Concentration Risk, Percentage	0.00%	13.00%

Fair Value Measurements (Detail

Fair Value Measurements (Details) - USD ($)	Sep. 30, 2016	Dec. 31, 2015	Sep. 30, 2015
Derivative Asset, Fair Value, Net [Abstract]
Derivative Current Asset, Fair Value	$ 6,800,000	$ 119,600,000
Derivative, Fair Value, Net [Abstract]
Fair Value, Assets, Level 1 to Level 2 Transfers, Amount	0		$ 0
Level 2 [Member] | Fair Value, Measurements, Recurring [Member]
Derivative, Fair Value, Net [Abstract]
Derivative Asset, Fair Value, Gross Asset (Liability)	(9,208,000)	119,550,000
Derivative Asset (Liability), Fair Value, Gross Liability (Asset)	0	0
Derivative, Fair Value, Gross Amount Not Offset Against Collateral, Net	(9,208,000)	119,550,000
Level 2 [Member] | Fair Value, Measurements, Recurring [Member] | Other Current Assets [Member]
Derivative Asset, Fair Value, Net [Abstract]
Derivative Current Asset, Fair Value, Gross Asset	31,742,000	159,447,000
Derivative Current Asset, Fair Value, Gross Liability	(11,596,000)	(28,347,000)
Derivative Current Asset, Fair Value	20,146,000	131,100,000
Level 2 [Member] | Fair Value, Measurements, Recurring [Member] | Other Noncurrent Assets [Member]
Derivative Asset, Fair Value, Net [Abstract]
Derivative Current Asset, Fair Value, Gross Asset	1,992,000	10,780,000
Derivative Current Asset, Fair Value, Gross Liability	(1,992,000)	(9,665,000)
Derivative Current Asset, Fair Value	0	1,115,000
Level 2 [Member] | Fair Value, Measurements, Recurring [Member] | Derivative Liabilities Current [Member]
Derivative Liability, Fair Value, Net [Abstract]
Derivative Liability, Fair Value, Gross Liability	11,596,000	28,364,000
Derivative Liability, Fair Value, Gross Asset	(11,596,000)	(28,347,000)
Derivative Liability	0	(17,000)
Level 2 [Member] | Fair Value, Measurements, Recurring [Member] | Other Noncurrent Liabilities [Member]
Derivative Liability, Fair Value, Net [Abstract]
Derivative Liability, Fair Value, Gross Liability	31,346,000	22,313,000
Derivative Liability, Fair Value, Gross Asset	(1,992,000)	(9,665,000)
Derivative Liability	$ (29,354,000)	$ (12,648,000)

Fair Value Measurements (Schedu

Fair Value Measurements (Schedule of Carrying Value and Estimated Fair Value of Debt Instruments) (Details) - USD ($) $ in Thousands	Sep. 30, 2016	Dec. 31, 2015
7.50% Senior Notes [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long term debt	$ 600,000	$ 600,000
7.50% Senior Notes [Member] | Reported Value Measurement [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long term debt	593,130	592,203
7.50% Senior Notes [Member] | Estimate of Fair Value Measurement [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long term debt	615,000	528,000
6.25% Senior Notes [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long term debt	650,000	650,000
6.25% Senior Notes [Member] | Reported Value Measurement [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long term debt	640,246	639,389
6.25% Senior Notes [Member] | Estimate of Fair Value Measurement [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long term debt	643,500	533,000
Other Long Term Debt [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long term debt	4,425	4,425
Other Long Term Debt [Member] | Reported Value Measurement [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long term debt	4,425	4,425
Other Long Term Debt [Member] | Estimate of Fair Value Measurement [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long term debt	$ 4,337	$ 4,182

Condensed Consolidating Finan48

Condensed Consolidating Financial Information (Narrative) (Details)	Sep. 30, 2016
Condensed Consolidating Financial Information [Abstract]
Voting interest of the subsidiary owned by the registrant	100.00%

Condensed Consolidating Finan49

Condensed Consolidating Financial Information (Schedule Of Condensed Consolidating Balance Sheet) (Details) - USD ($) $ in Thousands	Sep. 30, 2016	Dec. 31, 2015
Condensed Balance Sheet Statements, Captions [Line Items]
Total current assets	$ 77,513	$ 232,182
Total property and equipment, net	1,334,695	1,716,861
Investment in subsidiaries	0	0
Other assets	8,299	58,203
Total Assets	1,420,507	2,007,246
Current liabilities	229,762	285,484
Long-term liabilities	1,396,104	1,277,708
Total shareholders’ equity (deficit)	(205,359)	444,054
Total Liabilities and Shareholders’ Equity (Deficit)	1,420,507	2,007,246
Eliminations [Member]
Condensed Balance Sheet Statements, Captions [Line Items]
Total current assets	(2,524,333)	(2,397,919)
Total property and equipment, net	(3,855)	(2,471)
Investment in subsidiaries	1,338,051	815,836
Other assets	0	(16,632)
Total Assets	(1,190,137)	(1,601,186)
Current liabilities	(2,527,353)	(2,400,939)
Long-term liabilities	15,879	(753)
Total shareholders’ equity (deficit)	1,321,337	800,506
Total Liabilities and Shareholders’ Equity (Deficit)	(1,190,137)	(1,601,186)
Parent Company [Member] | Reportable Legal Entities [Member]
Condensed Balance Sheet Statements, Captions [Line Items]
Total current assets	2,551,367	2,578,034
Total property and equipment, net	42,759	44,499
Investment in subsidiaries	(1,338,051)	(815,836)
Other assets	8,143	74,679
Total Assets	1,264,218	1,881,376
Current liabilities	94,952	161,792
Long-term liabilities	1,357,911	1,260,200
Total shareholders’ equity (deficit)	(188,645)	459,384
Total Liabilities and Shareholders’ Equity (Deficit)	1,264,218	1,881,376
Combined Guarantor Subsidiaries [Member] | Reportable Legal Entities [Member]
Condensed Balance Sheet Statements, Captions [Line Items]
Total current assets	50,479	52,067
Total property and equipment, net	1,291,991	1,671,774
Investment in subsidiaries	0	0
Other assets	156	156
Total Assets	1,342,626	1,723,997
Current liabilities	2,658,363	2,521,572
Long-term liabilities	22,314	18,261
Total shareholders’ equity (deficit)	(1,338,051)	(815,836)
Total Liabilities and Shareholders’ Equity (Deficit)	1,342,626	1,723,997
Combined Non-Guarantor Subsidiaries [Member] | Reportable Legal Entities [Member]
Condensed Balance Sheet Statements, Captions [Line Items]
Total current assets	0	0
Total property and equipment, net	3,800	3,059
Investment in subsidiaries	0	0
Other assets	0	0
Total Assets	3,800	3,059
Current liabilities	3,800	3,059
Long-term liabilities	0	0
Total shareholders’ equity (deficit)	0	0
Total Liabilities and Shareholders’ Equity (Deficit)	$ 3,800	$ 3,059

Condensed Consolidating Finan50

Condensed Consolidating Financial Information (Schedule Of Condensed Consolidating Statement Of Operations) (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015
Condensed Income Statements, Captions [Line Items]
Total revenues	$ 111,177	$ 106,237	$ 299,763	$ 329,781
Total costs and expenses	212,664	917,920	974,458	1,247,451
Income (loss) from continuing operations before income taxes	(101,487)	(811,683)	(674,695)	(917,670)
Income tax (expense) benefit	313	102,915	0	140,456
Equity (deficit) in income of subsidiaries	0	0	0	0
Income (loss) from continuing operations	(101,174)	(708,768)	(674,695)	(777,214)
Income (loss) from discontinued operations, net of income taxes	0	1,121	0	2,225
Net Income (loss)	(101,174)	(707,647)	(674,695)	(774,989)
Eliminations [Member]
Condensed Income Statements, Captions [Line Items]
Total revenues	0	0	0	0
Total costs and expenses	66	34,288	431	28,987
Income (loss) from continuing operations before income taxes	(66)	(34,288)	(431)	(28,987)
Income tax (expense) benefit	313	8,564	0	7,154
Equity (deficit) in income of subsidiaries	72,975	664,501	523,168	657,369
Income (loss) from continuing operations	73,222	638,777	522,737	635,536
Income (loss) from discontinued operations, net of income taxes	0	0	0	0
Net Income (loss)	73,222	638,777	522,737	635,536
Parent Company [Member] | Reportable Legal Entities [Member]
Condensed Income Statements, Captions [Line Items]
Total revenues	105	235	349	1,485
Total costs and expenses	28,551	(6,718)	151,445	116,793
Income (loss) from continuing operations before income taxes	(28,446)	6,953	(151,096)	(115,308)
Income tax (expense) benefit	0	(25,496)	0	17,296
Equity (deficit) in income of subsidiaries	(72,975)	(664,501)	(523,168)	(657,369)
Income (loss) from continuing operations	(101,421)	(683,044)	(674,264)	(755,381)
Income (loss) from discontinued operations, net of income taxes	0	1,121	0	2,225
Net Income (loss)	(101,421)	(681,923)	(674,264)	(753,156)
Combined Guarantor Subsidiaries [Member] | Reportable Legal Entities [Member]
Condensed Income Statements, Captions [Line Items]
Total revenues	111,072	106,002	299,414	328,296
Total costs and expenses	184,047	890,350	822,582	1,101,671
Income (loss) from continuing operations before income taxes	(72,975)	(784,348)	(523,168)	(773,375)
Income tax (expense) benefit	0	119,847	0	116,006
Equity (deficit) in income of subsidiaries	0	0	0	0
Income (loss) from continuing operations	(72,975)	(664,501)	(523,168)	(657,369)
Income (loss) from discontinued operations, net of income taxes	0	0	0	0
Net Income (loss)	(72,975)	(664,501)	(523,168)	(657,369)
Combined Non-Guarantor Subsidiaries [Member] | Reportable Legal Entities [Member]
Condensed Income Statements, Captions [Line Items]
Total revenues	0	0	0	0
Total costs and expenses	0	0	0	0
Income (loss) from continuing operations before income taxes	0	0	0	0
Income tax (expense) benefit	0	0	0	0
Equity (deficit) in income of subsidiaries	0	0	0	0
Income (loss) from continuing operations	0	0	0	0
Income (loss) from discontinued operations, net of income taxes	0	0	0	0
Net Income (loss)	$ 0	$ 0	$ 0	$ 0

Condensed Consolidating Finan51

Condensed Consolidating Financial Information (Schedule Of Condensed Consolidating Statement Of Cash Flows) (Details) - USD ($) $ in Thousands	9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015
Condensed Cash Flow Statements, Captions [Line Items]
Net cash provided by (used in) operating activities - continuing operations	$ 197,847	$ 284,219
Net cash used in investing activities - continuing operations	(331,575)	(539,072)
Net cash provided by (used in) financing activities - continuing operations	94,045	249,391
Net cash provided by (used in) discontinued operations	0	(3,372)
Net Decrease in Cash and Cash Equivalents	(39,683)	(8,834)
Cash and Cash Equivalents, Beginning of Period	42,918	10,838
Cash and cash equivalents, end of period	3,235	2,004
Eliminations [Member]
Condensed Cash Flow Statements, Captions [Line Items]
Net cash provided by (used in) operating activities - continuing operations	0	0
Net cash used in investing activities - continuing operations	123,362	386,010
Net cash provided by (used in) financing activities - continuing operations	(123,362)	(386,010)
Net cash provided by (used in) discontinued operations	0	0
Net 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 Company [Member] | Reportable Legal Entities [Member]
Condensed Cash Flow Statements, Captions [Line Items]
Net cash provided by (used in) operating activities - continuing operations	(10,882)	(8,817)
Net cash used in investing activities - continuing operations	(122,846)	(396,036)
Net cash provided by (used in) financing activities - continuing operations	94,045	399,391
Net cash provided by (used in) discontinued operations	0	(3,372)
Net Decrease in Cash and Cash Equivalents	(39,683)	(8,834)
Cash and Cash Equivalents, Beginning of Period	42,918	10,838
Cash and cash equivalents, end of period	3,235	2,004
Combined Guarantor Subsidiaries [Member] | Reportable Legal Entities [Member]
Condensed Cash Flow Statements, Captions [Line Items]
Net cash provided by (used in) operating activities - continuing operations	208,729	293,036
Net cash used in investing activities - continuing operations	(331,351)	(529,046)
Net cash provided by (used in) financing activities - continuing operations	122,622	236,010
Net cash provided by (used in) discontinued operations	0	0
Net 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
Combined Non-Guarantor Subsidiaries [Member] | Reportable Legal Entities [Member]
Condensed Cash Flow Statements, Captions [Line Items]
Net cash provided by (used in) operating activities - continuing operations	0	0
Net cash used in investing activities - continuing operations	(740)	0
Net cash provided by (used in) financing activities - continuing operations	740	0
Net cash provided by (used in) discontinued operations	0	0
Net 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

Supplemental Cash Flow Inform52

Supplemental Cash Flow Information (Schedule of Cash Flow Supplemental Disclosures) (Details) - USD ($) $ in Thousands	9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015
Supplemental Cash Flow Elements [Abstract]
Change In Accrued Capital Expenditures And Capital Expenditure Payables	$ 7,316	$ (71,967)
Other Non-Cash Investing Activities	$ 12,468	$ 23,737

Subsequent Events (Narrative) (

Subsequent Events (Narrative) (Details) - USD ($) $ / shares in Units, $ in Thousands, shares in Millions	1 Months Ended		3 Months Ended	9 Months Ended
	Dec. 31, 2016	Oct. 31, 2016	Dec. 31, 2016	Sep. 30, 2016	Sep. 30, 2015	Oct. 28, 2016	Oct. 24, 2016	Mar. 31, 2016
Subsequent Event [Line Items]
Sale of common stock, net of offering costs				$ 0	$ 231,316
Subsequent Event [Member]
Subsequent Event [Line Items]
Agreed Upon Purchase Price of Oil and Gas Property and Equipment			$ 181,000
Payments to Acquire Oil and Gas Property	$ 171,000	$ 10,000
Stock Issued During Period, Shares, New Issues			6
Shares Issued, Price Per Share						$ 37.32
Sale of common stock, net of offering costs			$ 223,900
Senior Secured Revolving Credit Facility [Member]
Subsequent Event [Line Items]
Line of credit facility, current borrowing capacity				$ 600,000				$ 685,000
Senior Secured Revolving Credit Facility [Member] | Subsequent Event [Member]
Subsequent Event [Line Items]
Line of credit facility, current borrowing capacity							$ 600,000

Subsequent Events, Derivative I

Subsequent Events, Derivative Instruments (Schedule of Crude Oil Derivative Positions) (Details) - Subsequent Event [Member] - Swaps [Member] - Crude Oil [Member]	Oct. 28, 2016bbl / d$ / bbls
Energy Related Derivative Weighted Average Floor Price of $54.15 [Member] | 3Q 2017
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount | bbl / d	6,000
Weighted Average Floor Price ($/Bbls) | $ / bbls	54.15
Energy Related Derivative Weighted Average Floor Price of $55.01 [Member] | 4Q 2017
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount | bbl / d	3,000
Weighted Average Floor Price ($/Bbls) | $ / bbls	55.01

Subsequent Events, Derivative55

Subsequent Events, Derivative Instruments (Schedule of Natural Gas Derivative Positions) (Details) - Subsequent Event [Member] - Swaps [Member] - FY 2017 - Natural Gas Derivative Positions [Member]	Oct. 28, 2016MMBTU / d$ / MMBTU
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount | MMBTU / d	20,000
Weighted Average Floor Price ($/MMBtu) | $ / MMBTU	3.30