DNR Denbury Resources Inc

---

---

---

---

---

---

---

---

---

---

---

(1)

Future interest payable represents most of the interest due over the terms of our 9% Senior Secured Second Lien Notes due 2021 (the “2021 Senior Secured Notes”), 9¼% Senior Secured Second Lien Notes due 2022 (the “2022 Senior Secured Notes”), and to a small extent our previously outstanding 3½% Convertible Senior Notes due 2024 (the “2024 Convertible Senior Notes”) and has been accounted for as debt in accordance with FASC 470-60, Troubled Debt Restructuring by Debtors. Our current maturities of long-term debt as of September 30, 2018 include $102.2 million of future interest payable related to the 2021 Senior Secured Notes and 2022 Senior Secured Notes that is due within the next twelve months. See January 2018 Note Exchanges below for further discussion.

•	The maturity date was extended from December 9, 2019 to December 9, 2021, provided that the maturity date may occur earlier (between February 2021 and August 2021) if the 2021 Senior Secured Notes due in May 2021 or 6⅜% Senior Subordinated Notes due in August 2021 (the “2021 Subordinated Notes”) are not repaid or refinanced by their respective maturity dates;

---

•	The borrowing base and total commitments were reduced from $1.05 billion to $615 million in connection with a reduction in the number of lenders party to the Bank Credit Agreement;

•	The amount of junior lien debt we can incur was increased from $1.2 billion to $1.65 billion outstanding in the aggregate at any one time; and

•	A Consolidated Total Debt to Consolidated EBITDAX financial maintenance covenant was added with a ratio not to exceed 5.25 to 1.0 through December 31, 2020, and 4.50 to 1.0 thereafter through the maturity date.

•	A consolidated senior secured debt to consolidated EBITDAX covenant, with such ratio not to exceed 2.5 to 1.0. Currently, only debt under our Bank Credit Agreement is considered consolidated senior secured debt for purposes of this ratio;

•	A minimum permitted ratio of consolidated EBITDAX to consolidated interest charges of 1.25 to 1.0; and

•	A requirement to maintain a current ratio of 1.0 to 1.0.

---

---

(1)	Ranges presented for fixed-price swaps represent the lowest and highest fixed prices of all open contracts for the period presented. For three-way collars, ranges represent the lowest floor price and highest ceiling price for all open contracts for the period presented.

(2)

A three-way collar is a costless collar contract combined with a sold put feature (at a lower price) with the same counterparty. The value received for the sold put is used to enhance the contracted floor and ceiling price of the related collar. At the contract settlement date, (1) if the index price is higher than the ceiling price, we pay the counterparty the difference between the index price and ceiling price for the contracted volumes, (2) if the index price is between the floor and ceiling price, no settlements occur, (3) if the index price is lower than the floor price but at or above the sold put price, the counterparty pays us the difference between the index price and the floor price for the contracted volumes and (4) if the index price is lower than the sold put price, the counterparty pays us the difference between the floor price and the sold put price for the contracted volumes.

•	Level 1 – Quoted prices in active markets for identical assets or liabilities as of the reporting date.

---

•

Level 2 – Pricing inputs are other than quoted prices in active markets included in Level 1, which are either directly or indirectly observable as of the reported date. Level 2 includes those financial instruments that are valued using models or other valuation methodologies. Instruments in this category include non-exchange-traded oil derivatives that are based on NYMEX pricing and fixed-price swaps that are based on regional pricing other than NYMEX (e.g., Light Louisiana Sweet). Our costless collars and the sold put features of our three-way collars are valued using the Black-Scholes model, an industry standard option valuation model that takes into account inputs such as contractual prices for the underlying instruments, maturity, quoted forward prices for commodities, interest rates, volatility factors and credit worthiness, as well as other relevant economic measures. Substantially all of these assumptions are observable in the marketplace throughout the full term of the instrument, can be derived from observable data or are supported by observable levels at which transactions are executed in the marketplace.

•

Level 3 – Pricing inputs include significant inputs that are generally less observable. These inputs may be used with internally developed methodologies that result in management’s best estimate of fair value. As of September 30, 2018, instruments in this category include non-exchange-traded three-way collars that are based on regional pricing other than NYMEX (e.g., Light Louisiana Sweet). The valuation models utilized for costless collars and three-way collars are consistent with the methodologies described above; however, the implied volatilities utilized in the valuation of Level 3 instruments are developed using a benchmark, which is considered a significant unobservable input. An increase or decrease of 100 basis points in the implied volatility inputs utilized in our fair value measurement would result in a change of approximately $400 thousand in the fair value of these instruments as of September 30, 2018.

---

---

---

---

•	Oil and natural gas revenues in the third quarter of 2018 improved by $120.6 million, or 47%, principally driven by a 50% improvement in realized oil prices. Our net realized oil price relative to NYMEX prices improved by $2.18 per Bbl from the prior-year period to $1.84 per Bbl above NYMEX.

•	Commodity derivatives expense increased by $19.3 million ($44.6 million of expense in the current-year period compared to $25.3 million in the prior-year period). This increase in expense was the result of a $61.7 million increase in payments on derivative settlements, partially offset by a $42.4 million gain on noncash fair value adjustments between the periods.

---

•	During December 2017, we reduced debt principal by $143.6 million through privately negotiated transactions, in which institutional holders exchanged $609.8 million aggregate principal amount of our subordinated debt for:

–	$381.6 million aggregate principal amount of 9¼% Senior Secured Second Lien Notes due 2022 (the “2022 Senior Secured Notes”) and

–	$84.7 million aggregate principal amount of 3½% Convertible Senior Notes due 2024 (the “2024 Convertible Senior Notes”)

•	During January 2018, we reduced debt principal by $40.8 million through additional exchange transactions, in which institutional holders exchanged $174.3 million aggregate principal amount of our subordinated debt for:

–	$74.1 million aggregate principal amount of 2022 Senior Secured Notes and

–	$59.4 million aggregate principal amount of 5% Convertible Senior Notes due 2023 (the “2023 Convertible Senior Notes”)

•

In April and May 2018, we reduced debt principal by $144.1 million when holders of all outstanding 2024 Convertible Senior Notes and 2023 Convertible Senior Notes, issued in the exchanges above, converted their notes into shares of Denbury common stock, at rates specified in the indentures for the notes, which resulted in the issuance of 55.2 million shares of our common stock upon conversion. As of April 18, 2018 and May 30, 2018, there were no remaining 2024 Convertible Senior Notes or 2023 Convertible Senior Notes outstanding, with the conversion of these notes saving the Company annual cash interest payments of $5.9 million.

---

•	The maturity date was extended from December 9, 2019 to December 9, 2021, provided that the maturity date may occur earlier (between February 2021 and August 2021) if the 9% Senior Secured Second Lien Notes due in May 2021 (“2021 Senior Secured Notes”) or 6⅜% Senior Subordinated Notes due in August 2021 are not repaid or refinanced by their respective maturity dates;

•	The borrowing base and total commitments were reduced from $1.05 billion to $615 million in connection with a reduction in the number of lenders party to the Bank Credit Facility;

•	The amount of junior lien debt we can incur was increased from $1.2 billion to $1.65 billion outstanding in the aggregate at any one time; and

•	A Consolidated Total Debt to Consolidated EBITDAX financial maintenance covenant was added with a ratio not to exceed 5.25 to 1.0 through December 31, 2020, and 4.50 to 1.0 thereafter through the maturity date.

•	A consolidated senior secured debt to consolidated EBITDAX covenant, with such ratio not to exceed 2.5 to 1.0. Currently, only debt under our Bank Credit Agreement is considered consolidated senior secured debt for purposes of this ratio;

•	A minimum permitted ratio of consolidated EBITDAX to consolidated interest charges of 1.25 to 1.0; and

---

•	A requirement to maintain a current ratio of 1.0 to 1.0.

•	$155 million allocated for tertiary oil field expenditures;

•	$95 million allocated for other areas, primarily non-tertiary oil field expenditures including exploitation;

•	$20 million to be spent on CO2 sources and pipelines; and

•	$45 million for other capital items such as capitalized internal acquisition, exploration and development costs and pre-production tertiary startup costs.

(1)	Includes capitalized internal acquisition, exploration and development costs and pre-production tertiary startup costs.

---

---

---

(1)	Barrel of oil equivalent using the ratio of one barrel of oil to six Mcf of natural gas (“BOE”).

---

(2)	See also Commodity Derivative Contracts below and Item 3. Quantitative and Qualitative Disclosures about Market Risk for information concerning our derivative transactions.

(3)

Noncash fair value gains (losses) on commodity derivatives is a non-GAAP measure and is different from “Commodity derivatives expense (income)” in the Unaudited Condensed Consolidated Statements of Operations in that the noncash fair value gains (losses) on commodity derivatives represent only the net changes between periods of the fair market values of commodity derivative positions, and exclude the impact of settlements on commodity derivatives during the period, which were payments on settlements of $61.6 million and $149.7 million for the three and nine months ended September 30, 2018, respectively, compared to receipts on settlements of $0.1 million for the three months ended September 30, 2017 and payments on settlements of $38.6 million for the nine months ended September 30, 2017, respectively. We believe that noncash fair value gains (losses) on commodity derivatives is a useful supplemental disclosure to “Commodity derivatives expense (income)” in order to differentiate noncash fair market value adjustments from receipts or payments upon settlements on commodity derivatives during the period. This supplemental disclosure is widely used within the industry and by securities analysts, banks and credit rating agencies in calculating EBITDA and in adjusting net income (loss) to present those measures on a comparative basis across companies, as well as to assess compliance with certain debt covenants. Noncash fair value gains (losses) on commodity derivatives is not a measure of financial or operating performance under GAAP, nor should it be considered in isolation or as a substitute for “Commodity derivatives expense (income)” in the Unaudited Condensed Consolidated Statements of Operations.

(4)	Represents “Marketing and plant operating expenses” as presented in the Unaudited Condensed Consolidated Statements of Operations excluding expenses for purchases of oil from third-parties.

---

(1)	Mature properties include Brookhaven, Cranfield, Eucutta, Little Creek, Mallalieu, Martinville, McComb and Soso fields.

(2)	Represents production related to the acquisition of a 23% non-operated working interest in Salt Creek Field in Wyoming, which closed on June 30, 2017.

(3)	Includes production from Lockhart Crossing Field sold in the third quarter of 2018.

---

---

•

Gulf Coast Region. Our average NYMEX oil differential in the Gulf Coast region was a positive $3.21 per Bbl and a positive $0.01 per Bbl during the third quarters of 2018 and 2017, respectively, and a positive $1.12 per Bbl during the second quarter of 2018. These differentials are impacted significantly by the changes in prices received for our crude oil sold under LLS index prices relative to the changes in NYMEX prices, as well as various other price adjustments such as those noted above.  The average LLS-to-NYMEX differential (on a trade-month basis) averaged a positive $4.48 per Bbl in the third quarter of 2018, an increase from the positive $2.37 per Bbl in the third quarter of 2017 and a positive $3.32 per Bbl in the second quarter of 2018. During the third quarter of 2018, we sold approximately 60% of our crude oil at prices based on, or partially tied to, the LLS index price, and the balance at prices based on various other indexes tied to NYMEX prices, primarily in the Rocky Mountain region.

•

Rocky Mountain Region. NYMEX oil differentials in the Rocky Mountain region averaged $0.54 per Bbl and $0.98 per Bbl below NYMEX during the third quarters of 2018 and 2017, respectively, and $0.84 per Bbl below NYMEX during the second quarter of 2018. Differentials in the Rocky Mountain region can fluctuate significantly on a month-to-month basis due to weather, refinery or transportation issues, and Canadian and U.S. crude oil price index volatility.

---

(1)	Noncash fair value gains (losses) on commodity derivatives is a non-GAAP measure. See Operating Results Table above for a discussion of the reconciliation between noncash fair value gains (losses) on commodity derivatives to “Commodity derivatives expense (income)” in the Unaudited Condensed Consolidated Statements of Operations.

(1)	Averages are volume weighted.

(2)	If oil prices were to average less than the sold put price, receipts on settlement would be limited to the difference between the floor price and the sold put price.

---

---

---

(1)

Cash interest is presented on an accrual basis and includes the portion of interest on our 2021 Senior Secured Notes, 2022 Senior Secured Notes, 2023 Convertible Senior Notes and 2024 Convertible Senior Notes versus the GAAP financial statement presentation in which interest on these notes is accounted for as debt and not reflected as interest for financial reporting purposes in accordance with Financial Accounting Standards Board Codification 470-60, Troubled Debt Restructuring by Debtors. See below for further discussion.

(2)	Includes commitment fees but excludes debt issue costs.

---

---

(1)	Noncash fair value gains (losses) on commodity derivatives is a non-GAAP measure. See Operating Results Table above for a discussion of the reconciliation between noncash fair value gains (losses) on commodity derivatives to “Commodity derivatives expense (income)” in the Unaudited Condensed Consolidated Statements of Operations.

---

---

---

---

---

---

(1)	Shares purchased during the third quarter of 2018 were made in connection with the surrender of shares by our employees to satisfy their tax withholding requirements related to the vesting of restricted and performance shares.

(2)

In October 2011, we commenced a common share repurchase program, which has been approved for up to an aggregate of $1.162 billion of Denbury common shares by the Company’s Board of Directors. This program has effectively been suspended and we do not anticipate repurchasing shares of our common stock in the near future. The program has no pre-established ending date and may be suspended or discontinued at any time. We are not obligated to repurchase any dollar amount or specific number of shares of our common stock under the program.

---

*	Included herewith.

---

Attention:	Christian S. Kendall, President and Chief Executive Officer

---

---

---

---

---

---

---

---

---

---

a)	Pursuant to the agreement and plan of merger (together with all exhibits, schedules, annexes and disclosure schedules thereto, collectively, the “Acquisition Agreement”) dated the date hereof among the Company, Merger Sub, LLC Sub and the Target, the Company will consummate the Acquisition.

b)

You will obtain $400,000,000 in gross cash proceeds from the issuance of second lien secured notes (the “New Notes”) in a public offering or Rule 144A private placement/Reg S offering (the “New Note Offering”) or, if you are unable to issue the full amount of the New Notes at or prior to the time the Acquisition is consummated, a senior secured second lien bridge facility in an amount of up to $400,000,000 less the gross cash proceeds of New Notes sold in the New Note Offering.

c)

That certain Amended and Restated Credit Agreement, dated as of December 9, 2014 (as amended, supplemented or otherwise modified from time to time, the “Existing Credit Agreement”), by and among the Company, as borrower, JPMorgan, as administrative agent, and the lending institutions party thereto shall be amended to increase the Borrowing Base (as defined in Exhibit C) to $1,200,000,000 and make other modifications to the Existing Credit Agreement as set forth in Exhibit C (such amendments, the “RBL Amendment”); provided that, in the event that the requisite consents to approve the RBL Amendment are not obtained from the lenders under the Existing Credit Agreement (the “Existing Lenders”) after giving effect to any related assignments of the commitments and voting of the assignees of such commitments under the Existing Credit Agreement, then the Existing Credit Agreement will be amended and restated, with the effect that the loans and commitments under the Existing Credit Agreement will be refinanced on the terms set forth in Exhibit C (the “Refinancing RBL Facility”).

d)

Substantially simultaneously with the Acquisition, all outstanding obligations of the Target and its subsidiaries pursuant to (i) the Credit Agreement, dated as of September 12, 2016, by and among Penn Virginia Holding Corp., Penn Virginia Corporation, the lenders party thereto and Wells Fargo Bank, National Association, as administrative agent and issuing lender, and (ii) the Credit Agreement, dated as of September 29, 2017, by and among Penn Virginia Holding Corp., as borrower, Penn Virginia Corporation, the lenders party thereto and Jefferies Finance LLC, as

---

e)	The proceeds of the Facilities funded on the Closing Date, will be applied to pay (i) the consideration in connection with the Acquisition and any other payments required under the Acquisition Agreement, (ii) the fees and expenses incurred in connection with the Transactions (the amounts set forth in clauses (i) and (ii) above, collectively, the “Acquisition Costs”) and (iii) for the Refinancing.

---

---

---

---

---

---

---

---

---

---

---

---

---

---

---

---

---

---

RE:

[Bridge Loan Agreement], dated as of [___], 201[_] by and among Denbury Resources Inc., a Delaware corporation (the “Borrower”), the guarantors party thereto, the lenders party thereto and JPMorgan Chase Bank, N.A., as Administrative Agent (as amended, modified, extended, restated, replaced, or supplemented from time to time, the “Bridge Loan Agreement”; capitalized terms used herein and not otherwise defined shall have the meanings set forth in the Bridge Loan Agreement)

1.	The undersigned Authorized Officer of the Borrower is familiar with the properties, businesses, assets and liabilities of the Borrower and is duly authorized to execute this certificate on behalf of the Borrower.

2.	After giving effect to the [Initial Loans] and the other transactions contemplated by the Bridge Loan Agreement:

a.	The fair value of the assets of the Borrower and its subsidiaries on a consolidated basis, at a fair valuation, will exceed the debts and liabilities, subordinated, contingent or otherwise, of the Borrower and its subsidiaries on a consolidated basis;

b.

The present fair saleable value of the real and personal property of the Borrower and its subsidiaries on a consolidated basis will be greater than the amount that will be required to pay the probable liability of the Borrower and its subsidiaries on a consolidated basis on their debts and other liabilities, subordinated, contingent or otherwise, as such debts and other liabilities become absolute and matured;

c.	The Borrower and its subsidiaries on a consolidated basis will be able to pay their debts and liabilities, subordinated, contingent or otherwise, as such debts and liabilities become absolute and matured; and

d.	The Borrower and its subsidiaries on a consolidated basis will not have unreasonably small capital with which to conduct the businesses in which they are engaged as such businesses are now conducted and are proposed to be conducted after the date hereof.

---

---

1.	I have reviewed this report on Form 10-Q of Denbury Resources Inc. (the registrant);

2.	Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.	Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.	The registrant’s other certifying officers and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a)	Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b)	Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c)	Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d)	Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5.	The registrant’s other certifying officers and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

(a)	All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

(b)	Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

1.	I have reviewed this report on Form 10-Q of Denbury Resources Inc. (the registrant);

2.	Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.	Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.	The registrant’s other certifying officers and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a)	Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b)	Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c)	Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d)	Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5.	The registrant’s other certifying officers and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

(a)	All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

(b)	Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

1.	The Report fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934, as amended; and

2.	The Information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of Denbury.

v3.10.0.1

Document and Entity Information - shares	9 Months Ended
	Sep. 30, 2018	Oct. 31, 2018
Document And Company Information [Abstract]
Document Type	10-Q
Document Period End Date	Sep. 30, 2018
Amendment Flag	false
Document Fiscal Year Focus	2018
Document Fiscal Period Focus	Q3
Trading Symbol	DNR
Current Fiscal Year End Date	--12-31
Entity Central Index Key	0000945764
Entity Current Reporting Status	Yes
Entity Filer Category	Large Accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Registrant Name	Denbury Resources Inc.
Entity Common Stock, Shares Outstanding		460,546,469

v3.10.0.1

Condensed Consolidated Balance Sheets (Unaudited) - USD ($) $ in Thousands		Sep. 30, 2018	Dec. 31, 2017
Current assets
Cash and cash equivalents		$ 66,711	$ 58
Accrued production receivable		163,475	146,334
Trade and other receivables, net		43,495	45,193
Other current assets		14,504	10,670
Total current assets		288,185	202,255
Oil and natural gas properties (using full cost accounting)
Proved properties		10,977,038	10,775,792
Unevaluated properties		976,378	951,397
CO2 properties		1,194,133	1,191,058
Pipelines and plants		2,299,699	2,286,047
Other property and equipment		286,443	339,218
Less accumulated depletion, depreciation, amortization and impairment		(11,477,873)	(11,376,646)
Net property and equipment		4,255,818	4,166,866
Other assets		100,014	102,178
Total assets		4,644,017	4,471,299
Current liabilities
Accounts payable and accrued liabilities		201,373	177,220
Oil and gas production payable		72,824	76,588
Derivative liabilities		125,354	99,061
Current maturities of long-term debt (including future interest payable of $102,181 and $75,347, respectively - see Note 4)	[1]	126,884	105,188
Total current liabilities		526,435	458,057
Long-term liabilities
Long-term debt, net of current portion (including future interest payable of $190,410 and $241,472, respectively - see Note 4)		2,693,424	2,979,086
Asset retirement obligations		174,761	165,756
Derivative liabilities		13,570	0
Deferred tax liabilities, net		249,264	198,099
Other liabilities		23,379	22,136
Total long-term liabilities		3,154,398	3,365,077
Commitments and contingencies (Note 7)
Stockholders' equity
Preferred stock, $.001 par value, 25,000,000 shares authorized, none issued and outstanding		0	0
Common stock, $.001 par value, 600,000,000 shares authorized; 462,462,855 and 402,549,346 shares issued, respectively		462	403
Paid-in capital in excess of par		2,680,899	2,507,828
Accumulated deficit		(1,707,591)	(1,855,810)
Treasury stock, at cost, 1,893,882 and 457,041 shares, respectively		(10,586)	(4,256)
Total stockholders' equity		963,184	648,165
Total liabilities and stockholders' equity		$ 4,644,017	$ 4,471,299
[1] Future interest payable represents most of the interest due over the terms of our 9% Senior Secured Second Lien Notes due 2021 (the “2021 Senior Secured Notes”), 9¼% Senior Secured Second Lien Notes due 2022 (the “2022 Senior Secured Notes”), and to a small extent our previously outstanding 3½% Convertible Senior Notes due 2024 (the “2024 Convertible Senior Notes”) and has been accounted for as debt in accordance with FASC 470-60, Troubled Debt Restructuring by Debtors. Our current maturities of long-term debt as of September 30, 2018 include $102.2 million of future interest payable related to the 2021 Senior Secured Notes and 2022 Senior Secured Notes that is due within the next twelve months. See January 2018 Note Exchanges below for further discussion.

v3.10.0.1

Condensed Consolidated Balance Sheets (Unaudited) (Parenthetical) - USD ($) $ in Thousands		Sep. 30, 2018	Dec. 31, 2017
Debt Instrument [Line Items]
Future interest payable - current	[1]	$ 126,884	$ 105,188
Future interest payable - long-term		$ 2,693,424	$ 2,979,086
Stockholders' equity
Preferred stock, par value		$ 0.001	$ 0.001
Preferred stock, shares authorized		25,000,000	25,000,000
Preferred stock, shares issued		0	0
Preferred stock, shares outstanding		0	0
Common stock, par value		$ 0.001	$ 0.001
Common stock, shares authorized		600,000,000	600,000,000
Common stock, shares issued		462,462,855	402,549,346
Treasury stock, shares		1,893,882	457,041
Future interest payable on senior secured and convertible senior notes
Debt Instrument [Line Items]
Future interest payable - current		$ 102,181	$ 75,347
Future interest payable - long-term		$ 190,410	$ 241,472
[1] Future interest payable represents most of the interest due over the terms of our 9% Senior Secured Second Lien Notes due 2021 (the “2021 Senior Secured Notes”), 9¼% Senior Secured Second Lien Notes due 2022 (the “2022 Senior Secured Notes”), and to a small extent our previously outstanding 3½% Convertible Senior Notes due 2024 (the “2024 Convertible Senior Notes”) and has been accounted for as debt in accordance with FASC 470-60, Troubled Debt Restructuring by Debtors. Our current maturities of long-term debt as of September 30, 2018 include $102.2 million of future interest payable related to the 2021 Senior Secured Notes and 2022 Senior Secured Notes that is due within the next twelve months. See January 2018 Note Exchanges below for further discussion.

v3.10.0.1

Condensed Consolidated Statements of Operations (Unaudited) - USD ($) shares in Thousands, $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 2017
Revenues	$ 394,973	$ 266,559	$ 1,135,270	$ 803,197
Expenses
CO2 discovery and operating expenses	708	1,346	1,670	2,452
Taxes other than income	27,344	20,233	81,897	62,848
General and administrative expenses	21,579	27,273	61,223	81,303
Interest, net of amounts capitalized of $9,514, $9,416, $26,817 and $22,217, respectively	18,527	24,546	51,974	75,785
Depletion, depreciation, and amortization	51,316	52,101	156,711	154,448
Commodity derivatives expense (income)	44,577	25,263	189,601	(9,712)
Other expenses	1,933	0	7,241	0
Total expenses	300,938	280,346	947,984	749,808
Income (loss) before income taxes	94,035	(13,787)	187,286	53,389
Income tax provision (benefit)	15,616	(14,229)	39,067	17,018
Net income	$ 78,419	$ 442	$ 148,219	$ 36,371
Net income per common share
Basic	$ 0.17	$ 0.00	$ 0.35	$ 0.09
Diluted	$ 0.17	$ 0.00	$ 0.33	$ 0.09
Weighted average common shares outstanding
Basic	451,256	392,013	426,036	390,448
Diluted	458,450	393,023	455,934	392,625
Other income
Revenues	$ 7,196	$ 939	$ 17,640	$ 8,576
Lease operating expenses
Operating expenses	122,527	117,768	361,267	342,926
Marketing and plant operating expenses
Operating expenses	12,427	11,816	36,400	39,758
Oil, natural gas, and related product sales
Revenues	379,628	259,030	1,095,214	776,088
CO2 sales and transportation fees
Revenues	$ 8,149	$ 6,590	$ 22,416	$ 18,533

v3.10.0.1

Condensed Consolidated Statements of Operations (Unaudited) (Parenthetical) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 2017
Expenses
Capitalized interest	$ 9,514	$ 9,416	$ 26,817	$ 22,217

v3.10.0.1

Condensed Consolidated Statements of Cash Flows (Unaudited) - USD ($) $ in Thousands	9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017
Cash flows from operating activities
Net income	$ 148,219	$ 36,371
Adjustments to reconcile net income to cash flows from operating activities
Depletion, depreciation, and amortization	156,711	154,448
Deferred income taxes	42,741	35,846
Stock-based compensation	8,711	12,215
Commodity derivatives expense (income)	189,601	(9,712)
Payment on settlements of commodity derivatives	(149,738)	(38,618)
Debt issuance costs	4,980	4,801
Other, net	(7,066)	(112)
Changes in assets and liabilities, net of effects from acquisitions
Accrued production receivable	(17,140)	3,590
Trade and other receivables	139	(13,604)
Other current and long-term assets	(4,467)	(4,734)
Accounts payable and accrued liabilities	27,435	(22,736)
Oil and natural gas production payable	(3,764)	(10,848)
Other liabilities	(2,832)	(4,048)
Net cash provided by operating activities	393,530	142,859
Cash flows from investing activities
Oil and natural gas capital expenditures	(210,504)	(197,982)
Acquisitions of oil and natural gas properties	(151)	(91,124)
Pipelines and plants capital expenditures	(19,134)	(1,479)
Net proceeds from sales of oil and natural gas properties and equipment	7,308	1,412
Other	5,749	(4,638)
Net cash used in investing activities	(216,732)	(293,811)
Cash flows from financing activities
Bank repayments	(1,943,653)	(1,188,000)
Bank borrowings	1,468,653	1,382,000
Interest payments treated as a reduction of debt	(37,233)	(25,139)
Proceeds from issuance of senior secured notes	450,000	0
Cost of debt financing	(15,933)	(341)
Pipeline financing and capital lease debt repayments	(18,353)	(20,523)
Other	(13,288)	1,603
Net cash provided by (used in) financing activities	(109,807)	149,600
Net increase (decrease) in cash, cash equivalents, and restricted cash	66,991	(1,352)
Cash, cash equivalents, and restricted cash at beginning of period	15,992	17,050
Cash, cash equivalents, and restricted cash at end of period	$ 82,983	$ 15,698

v3.10.0.1

Condensed Consolidated Statement of Changes in Stockholders' Equity (Unaudited) - 9 months ended Sep. 30, 2018 - USD ($) $ in Thousands	Total	Common Stock ($.001 Par Value)	Paid-In Capital in Excess of Par	Retained Earnings (Accumulated Deficit)	Treasury Stock (at cost)
Beginning balance, shares at Dec. 31, 2017	402,549,346	402,549,346			457,041
Beginning balance at Dec. 31, 2017	$ 648,165	$ 403	$ 2,507,828	$ (1,855,810)	$ (4,256)
Issued or purchased pursuant to stock compensation plans, shares		4,663,554
Issued or purchased pursuant to stock compensation plans, value		$ 4	(4)
Issued pursuant to notes conversion, shares		55,249,955
Issued pursuant to notes conversion, value	162,004	$ 55	161,949
Stock-based compensation, value	11,126		11,126
Tax withholding - stock compensation, shares					1,436,841
Tax withholding - stock compensation, value	(6,330)				$ (6,330)
Net income	$ 148,219			148,219
Ending balance, shares at Sep. 30, 2018	462,462,855	462,462,855			1,893,882
Ending balance at Sep. 30, 2018	$ 963,184	$ 462	$ 2,680,899	$ (1,707,591)	$ (10,586)

v3.10.0.1

Basis of Presentation	9 Months Ended
	Sep. 30, 2018
Accounting Policies [Abstract]
Basis of Presentation and Significant Accounting Policies	Note 1. Basis of Presentation Organization and Nature of Operations Denbury Resources Inc., a Delaware corporation, is an independent oil and natural gas company with operations focused in two key operating areas: the Gulf Coast and Rocky Mountain regions.  Our goal is to increase the value of our properties through a combination of exploitation, drilling and proven engineering extraction practices, with the most significant emphasis relating to CO2 enhanced oil recovery operations. Interim Financial Statements The accompanying unaudited condensed consolidated financial statements of Denbury Resources Inc. and its subsidiaries have been prepared in accordance with the rules and regulations of the Securities and Exchange Commission (“SEC”) and do not include all of the information and footnotes required by accounting principles generally accepted in the United States for complete financial statements.  These financial statements and the notes thereto should be read in conjunction with our Annual Report on Form 10-K for the year ended December 31, 2017 (the “Form 10-K”).  Unless indicated otherwise or the context requires, the terms “we,” “our,” “us,” “Company” or “Denbury,” refer to Denbury Resources Inc. and its subsidiaries. Accounting measurements at interim dates inherently involve greater reliance on estimates than at year end, and the results of operations for the interim periods shown in this report are not necessarily indicative of results to be expected for the year.  In management’s opinion, the accompanying unaudited condensed consolidated financial statements include all adjustments of a normal recurring nature necessary for a fair statement of our consolidated financial position as of September 30, 2018, our consolidated results of operations for the three and nine months ended September 30, 2018 and 2017, our consolidated cash flows for the nine months ended September 30, 2018 and 2017, and our consolidated statement of changes in stockholders’ equity for the nine months ended September 30, 2018. Reclassifications Certain prior period amounts have been reclassified to conform to the current year presentation. Such reclassifications had no impact on our reported net income, current assets, total assets, current liabilities, total liabilities or stockholders’ equity. Cash, Cash Equivalents, and Restricted Cash The following table provides a reconciliation of cash, cash equivalents, and restricted cash as reported within the Unaudited Condensed Consolidated Balance Sheets to “Cash, cash equivalents, and restricted cash at end of period” as reported within the Unaudited Condensed Consolidated Statements of Cash Flows: In thousands   September 30, 2018   December 31, 2017 Cash and cash equivalents   $ 66,711   $ 58 Restricted cash included in Other assets   16,272   15,934 Total cash, cash equivalents, and restricted cash shown in the Unaudited Condensed Consolidated Statements of Cash Flows   $ 82,983   $ 15,992 Amounts included in restricted cash included in “Other assets” in the accompanying Unaudited Condensed Consolidated Balance Sheets represent escrow accounts that are legally restricted for certain of our asset retirement obligations. Net Income per Common Share Basic net income per common share is computed by dividing the net income attributable to common stockholders by the weighted average number of shares of common stock outstanding during the period.  Diluted net income per common share is calculated in the same manner, but includes the impact of potentially dilutive securities.  Potentially dilutive securities consist of nonvested restricted stock, nonvested performance-based equity awards, and shares into which our previously-outstanding convertible senior notes were convertible. The following table sets forth the reconciliations of net income and weighted average shares used for purposes of calculating the basic and diluted net income per common share for the periods indicated:     Three Months Ended   Nine Months Ended     September 30,   September 30, In thousands   2018   2017   2018   2017 Numerator                 Net income – basic   $ 78,419   $ 442   $ 148,219   $ 36,371 Effect of potentially dilutive securities                 Interest on convertible senior notes   —   —   538   — Net income – diluted   $ 78,419   $ 442   $ 148,757   $ 36,371                   Denominator                 Weighted average common shares outstanding – basic   451,256   392,013   426,036   390,448 Effect of potentially dilutive securities                 Restricted stock and performance-based equity awards   7,194   1,010   6,983   2,177 Convertible senior notes   —   —   22,915   — Weighted average common shares outstanding – diluted   458,450   393,023   455,934   392,625 Basic weighted average common shares exclude shares of nonvested restricted stock. As these restricted shares vest, they will be included in the shares outstanding used to calculate basic net income per common share (although time-vesting restricted stock is issued and outstanding upon grant). For purposes of calculating diluted weighted average common shares during the three and nine months ended September 30, 2018 and 2017, the nonvested restricted stock and performance-based equity awards are included in the computation using the treasury stock method, with the deemed proceeds equal to the average unrecognized compensation during the period, and for the shares underlying the previously-outstanding convertible senior notes as if the convertible senior notes were converted at the beginning of the 2018 period. In April and May 2018, all outstanding convertible senior notes converted into shares of Denbury common stock, resulting in the issuance of 55.2 million shares of our common stock upon conversion. These shares have been included in basic weighted average common shares outstanding beginning on the date of conversion. See Note 4, Long-Term Debt, for further discussion. The following securities could potentially dilute earnings per share in the future, but were excluded from the computation of diluted net income per share, as their effect would have been antidilutive:     Three Months Ended   Nine Months Ended     September 30,   September 30, In thousands   2018   2017   2018   2017 Stock appreciation rights   2,689   4,551   2,824   4,793 Restricted stock and performance-based equity awards   —   9,891   203   6,259 Recent Accounting Pronouncements Recently Adopted Cash Flows. In November 2016, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update (“ASU”) 2016-18, Statement of Cash Flows (“ASU 2016-18”). ASU 2016-18 addresses the diversity that exists in the classification and presentation of changes in restricted cash on the statement of cash flows, and requires that a statement of cash flows explain the change in total cash, cash equivalents, and amounts generally described as restricted cash or restricted cash equivalents. Therefore, entities will no longer present transfers between cash and cash equivalents and restricted cash and restricted cash equivalents in the statement of cash flows. Effective January 1, 2018, we adopted ASU 2016-18, which has been applied retrospectively for all comparative periods presented. Accordingly, restricted cash associated with our escrow accounts of $15.9 million and $15.4 million for the nine-month periods ended September 30, 2018 and 2017, respectively, have been included in “Cash, cash equivalents, and restricted cash at beginning of period” on our Unaudited Condensed Consolidated Statements of Cash Flows and $15.6 million included in “Cash, cash equivalents, and restricted cash at end of period” for the nine-month period ended September 30, 2017. The adoption of ASU 2016-18 did not have an impact on our consolidated balance sheets or results of operations. Our quarterly reports on Form 10-Q for the periods ended March 31, 2018 and June 30, 2018, filed with the SEC on May 10, 2018 and August 9, 2018, respectively, incorrectly included in the beginning-of-period and end-of-period balances of “Cash, cash equivalents, and restricted cash” in our Statements of Cash Flows, certain U.S. Treasury Notes held in escrow accounts legally restricted for use in certain of our asset retirement obligations. Under Financial Accounting Standards Board Codification (“FASC”) 230-10-20, these notes do not meet the definition of restricted cash and restricted cash equivalents due to their maturity date exceeding 90 days. Previously disclosed balances of these U.S. Treasury Notes of $24.6 million, $25.2 million and $25.4 million as of January 1, 2018 (the date of adoption), March 31, 2018 and June 30, 2018, respectively, should have been excluded from “Cash, cash equivalents, and restricted cash” on the Consolidated Statements of Cash Flows.  Accordingly, “Cash, cash equivalents, and restricted cash” as of January 1, 2018 (the date of adoption), March 31, 2018 and June 30, 2018, originally reported as $40.6 million, $40.9 million and $41.6 million, respectively, should have been reported as $16.0 million, $15.7 million and $16.2 million, respectively.  In addition, changes in the U.S. Treasury Notes of $0.6 million and $0.8 million during the three months ended March 31, 2018 and six months ended June 30, 2018, respectively, should have been included in net cash used in investing activities. Accordingly, net cash used in investing activities for the three months ended March 31, 2018, originally reported as $50.8 million, should have been $51.4 million, and net cash used in investing activities for the six months ended June 30, 2018, originally reported as $134.1 million, should have been $134.9 million. Management has evaluated the quantitative and qualitative impact of the error to previously issued unaudited consolidated statements of cash flows and concluded that the previously issued consolidated financial statements were not materially misstated.  However, management has elected to revise the unaudited consolidated statements of cash flows for each of the three months ended March 31, 2018 and six months ended June 30, 2018 in its future filings.  These revisions had no impact on the Company’s financial condition or results of operations for the periods presented. Revenue Recognition. In May 2014, the FASB issued ASU 2014-09, Revenue from Contracts with Customers (“ASU 2014-09”). ASU 2014-09 amends the guidance for revenue recognition to replace numerous, industry-specific requirements. The core principle of the ASU is that an entity should recognize revenue for the transfer of goods or services equal to the amount that it expects to be entitled to receive for those goods or services. The ASU implements a five-step process for customer contract revenue recognition that focuses on transfer of control, as opposed to transfer of risk and rewards. The amendment also requires enhanced disclosures regarding the nature, amount, timing and uncertainty of revenues and cash flows arising from contracts with customers. In March, April and May 2016, the FASB issued four additional ASUs which primarily clarified the implementation guidance on principal versus agent considerations, performance obligations and licensing, collectibility, presentation of sales taxes and other similar taxes collected from customers, and non-cash consideration. Effective January 1, 2018, we adopted ASU 2014-09 using the modified retrospective method. The adoption of ASU 2014-09 did not have an impact on our consolidated financial statements, but required enhanced footnote disclosures. See Note 2, Revenue Recognition, for additional information. Not Yet Adopted Fair Value Measurement. In August 2018, the FASB issued ASU 2018-13, Fair Value Measurement (Topic 820) – Disclosure Framework – Changes to the Disclosure Requirements for Fair Value Measurements (“ASU 2018-13”). ASU 2018-13 adds, modifies, or removes certain disclosure requirements for recurring and nonrecurring fair value measurements based on the FASB’s consideration of costs and benefits. The amendments in this ASU are effective for fiscal years beginning after December 15, 2019, and interim periods within those fiscal years, and early adoption is permitted. Entities must adopt the amendments on changes in unrealized gains and losses, the range and weighted average of significant unobservable inputs used to develop Level 3 fair value measurements, and the narrative description of measurement uncertainty prospectively, and all other amendments should be applied retrospectively to all periods presented. The adoption of ASU 2018-13 is currently not expected to have a material effect on our consolidated financial statements, but may require enhanced footnote disclosures. Leases. In February 2016, the FASB issued ASU 2016-02, Leases (“ASU 2016-02”). ASU 2016-02 amends the guidance for lease accounting to require lease assets and liabilities to be recognized on the balance sheet, along with additional disclosures regarding key leasing arrangements. The ASU does not apply to mineral leases or leases that convey the right to explore for or use the land on which oil, natural gas, and similar natural resources are contained. The amendments in this ASU are effective for fiscal years beginning after December 15, 2018, and interim periods within those fiscal years, and early adoption is permitted. Entities must adopt the standard using a modified retrospective transition and apply the guidance to the earliest comparative period presented, with certain practical expedients that entities may elect to apply. In January 2018, the FASB issued ASU 2018-01, Leases (Topic 842) – Land Easement Practical Expedient for Transition to Topic 842, which provides an optional practical expedient to existing or expired land easements that were not previously accounted for as leases under Topic 840, which permits a company to evaluate only new or modified land easements under the new guidance. We intend to elect the practical expedients provided in the new ASUs that allow historical lease classification of existing leases, allow entities to recognize leases with terms of one year or less in their statement of operations, and carry forward our accounting treatment for existing land easement agreements. We are currently evaluating our lease agreements and implementing a software system to summarize the key contract terms and financial information associated with each lease agreement, in order to assess the impact the adoption of ASU 2016-02 and ASU 2018-01 will have on our consolidated financial statements.

v3.10.0.1

Revenue Recognition	9 Months Ended
	Sep. 30, 2018
Revenue from Contract with Customer [Abstract]
Revenue Recognition	Note 2. Revenue Recognition We record revenue in accordance with FASC Topic 606, Revenue from Contracts with Customers, which we adopted on January 1, 2018, and applied to all existing contracts using the modified retrospective method. The core principle of FASC Topic 606 is that an entity should recognize revenue for the transfer of goods or services equal to the amount of consideration that it expects to be entitled to receive for those goods or services. This principle is achieved through applying a five-step process for customer contract revenue recognition: •Identify the contract or contracts with a customer – We derive the majority of our revenues from oil and natural gas sales contracts and CO2 sales and transportation contracts. The contracts specify each party’s rights regarding the goods or services to be transferred and contain commercial substance as they impact our financial statements. A high percentage of our receivables balance is current, and we have not historically entered into contracts with counterparties that pose a credit risk without requiring adequate economic protection to ensure collection. •Identify the performance obligations in the contract – Each of our revenue contracts specify a volume per day, or production from a lease designated in the contract (a distinct good), to be delivered at the delivery point over the term of the contract (the identified performance obligation). The customer takes delivery and physical possession of the product at the delivery point, which generally is also the point at which title transfers and the customer obtains the risks and rewards of ownership (the identified performance obligation is satisfied). •Determine the transaction price – Typically, our oil and natural gas contracts define the price as a formula price based on the average market price, as specified on set dates each month, for the specific commodity during the month of delivery. Certain of our CO2 contracts define the price as a fixed contractual price adjusted to an inflation index to reflect market pricing. Given the industry practice to invoice customers the month following the month of delivery and our high probability of collection of payment, no significant financing component is included in our contracts. •Allocate the transaction price to the performance obligations in the contract – The majority of our revenue contracts are short-term, with terms of one year or less, to which we have applied the practical expedient permitted under the standard eliminating the requirement to disclose the transaction price allocated to remaining performance obligations. In limited instances, we have revenue contracts with terms greater than one year; however, the future delivery volumes are wholly unsatisfied as they represent separate performance obligations with variable consideration. We utilized the practical expedient which eliminates the requirement to disclose the transaction price allocated to remaining performance obligations if the variable consideration is allocated entirely to wholly unsatisfied performance obligations. As there is only one performance obligation associated with our contracts, no allocation of the transaction price is necessary. •Recognize revenue when, or as, we satisfy a performance obligation – Once we have delivered the volume of commodity to the delivery point and the customer takes delivery and possession, we are entitled to payment and we invoice the customer for such delivered production. Payment under most oil and CO2 contracts is made within a month following product delivery and for natural gas and NGL contracts is generally made within two months following delivery. Timing of revenue recognition may differ from the timing of invoicing to customers; however, as the right to consideration after delivery is unconditional based on only the passage of time before payment of the consideration is due, upon delivery we record a receivable in “Accrued production receivable” in our Unaudited Condensed Consolidated Balance Sheets, which was $163.5 million and $146.3 million as of September 30, 2018 and December 31, 2017, respectively. Disaggregation of Revenue The following table summarizes our revenues by product type for the three and nine months ended September 30, 2018 and 2017:     Three Months Ended   Nine Months Ended     September 30,   September 30, In thousands   2018   2017   2018   2017 Oil sales   $ 377,329   $ 256,621   $ 1,088,021   $ 768,912 Natural gas sales   2,299   2,409   7,193   7,176 CO2 sales and transportation fees   8,149   6,590   22,416   18,533 Total revenues   $ 387,777   $ 265,620   $ 1,117,630   $ 794,621

v3.10.0.1

Assets Held for Sale	9 Months Ended
	Sep. 30, 2018
Assets Held-for-sale, Not Part of Disposal Group [Abstract]
Assets Held for Sale	Note 3. Assets Held for Sale We are marketing for sale certain non-productive surface acreage in the Houston area. As of September 30, 2018, the carrying value of the land held for sale was $33.0 million, which is included in “Other property and equipment” on our Unaudited Condensed Consolidated Balance Sheets.

v3.10.0.1

Long-Term Debt	9 Months Ended
	Sep. 30, 2018
Debt Disclosure [Abstract]
Long-Term Debt	Note 4. Long-Term Debt The table below reflects long-term debt and capital lease obligations outstanding as of the dates indicated:     September 30,   December 31, In thousands   2018   2017 Senior Secured Bank Credit Agreement   $ —   $ 475,000 9% Senior Secured Second Lien Notes due 2021   614,919   614,919 9¼% Senior Secured Second Lien Notes due 2022   455,668   381,568 7½% Senior Secured Second Lien Notes due 2024   450,000   — 3½% Convertible Senior Notes due 2024   —   84,650 6⅜% Senior Subordinated Notes due 2021   203,545   215,144 5½% Senior Subordinated Notes due 2022   314,662   408,882 4⅝% Senior Subordinated Notes due 2023   307,978   376,501 Pipeline financings   183,428   192,429 Capital lease obligations   11,290   26,298 Total debt principal balance   2,541,490   2,775,391 Future interest payable(1)   292,590   316,818 Debt issuance costs   (13,772 )   (7,935 ) Total debt, net of debt issuance costs   2,820,308   3,084,274 Less: current maturities of long-term debt(1)   (126,884 )   (105,188 ) Long-term debt and capital lease obligations   $ 2,693,424   $ 2,979,086 (1) Future interest payable represents most of the interest due over the terms of our 9% Senior Secured Second Lien Notes due 2021 (the “2021 Senior Secured Notes”), 9¼% Senior Secured Second Lien Notes due 2022 (the “2022 Senior Secured Notes”), and to a small extent our previously outstanding 3½% Convertible Senior Notes due 2024 (the “2024 Convertible Senior Notes”) and has been accounted for as debt in accordance with FASC 470-60, Troubled Debt Restructuring by Debtors. Our current maturities of long-term debt as of September 30, 2018 include $102.2 million of future interest payable related to the 2021 Senior Secured Notes and 2022 Senior Secured Notes that is due within the next twelve months. See January 2018 Note Exchanges below for further discussion. The ultimate parent company in our corporate structure, Denbury Resources Inc. (“DRI”), is the sole issuer of all of our outstanding senior secured and senior subordinated notes. DRI has no independent assets or operations. Each of the subsidiary guarantors of such notes is 100% owned, directly or indirectly, by DRI, and the guarantees of the notes are full and unconditional and joint and several; any subsidiaries of DRI that are not subsidiary guarantors of such notes are minor subsidiaries. Senior Secured Bank Credit Facility In December 2014, we entered into an Amended and Restated Credit Agreement with JPMorgan Chase Bank, N.A., as administrative agent, and other lenders party thereto (as amended, the “Bank Credit Agreement”). The Bank Credit Agreement is a senior secured revolving credit facility with semiannual borrowing base redeterminations in May and November of each year, with the next such redetermination being scheduled for May 2019. If our outstanding debt under the Bank Credit Agreement were to ever exceed the borrowing base, we would be required to repay the excess amount over a period not to exceed six months. We incur a commitment fee of 0.50% on the undrawn portion of the aggregate lender commitments under the Bank Credit Agreement. In August 2018, we entered into the Sixth Amendment to the Bank Credit Agreement (the “Sixth Amendment”), pursuant to which the following changes were made to the Bank Credit Agreement: • The maturity date was extended from December 9, 2019 to December 9, 2021, provided that the maturity date may occur earlier (between February 2021 and August 2021) if the 2021 Senior Secured Notes due in May 2021 or 6⅜% Senior Subordinated Notes due in August 2021 (the “2021 Subordinated Notes”) are not repaid or refinanced by their respective maturity dates; • The borrowing base and total commitments were reduced from $1.05 billion to $615 million in connection with a reduction in the number of lenders party to the Bank Credit Agreement; • The amount of junior lien debt we can incur was increased from $1.2 billion to $1.65 billion outstanding in the aggregate at any one time; and • A Consolidated Total Debt to Consolidated EBITDAX financial maintenance covenant was added with a ratio not to exceed 5.25 to 1.0 through December 31, 2020, and 4.50 to 1.0 thereafter through the maturity date. At September 30, 2018, in addition to the Consolidated Total Debt to Consolidated EBITDAX covenant added by the Sixth Amendment, the Bank Credit Agreement contains certain financial performance covenants through the maturity of the facility, including the following: • A consolidated senior secured debt to consolidated EBITDAX covenant, with such ratio not to exceed 2.5 to 1.0. Currently, only debt under our Bank Credit Agreement is considered consolidated senior secured debt for purposes of this ratio; • A minimum permitted ratio of consolidated EBITDAX to consolidated interest charges of 1.25 to 1.0; and • A requirement to maintain a current ratio of 1.0 to 1.0. As of September 30, 2018, we had no outstanding borrowings and were in compliance with all debt covenants under the Bank Credit Agreement. The above description of our Bank Credit Agreement is qualified by the express language and defined terms contained in the Bank Credit Agreement and the amendments thereto, each of which are filed as exhibits to our periodic reports filed with the SEC. January 2018 Note Exchanges During January 2018, we closed transactions to exchange a total of $174.3 million aggregate principal amount of our then existing senior subordinated notes for $74.1 million aggregate principal amount of new 2022 Senior Secured Notes and $59.4 million aggregate principal amount of new 5% Convertible Senior Notes due 2023 (the “2023 Convertible Senior Notes”), resulting in a net reduction in our debt principal from these exchanges of $40.8 million. The exchanged notes consisted of $11.6 million aggregate principal amount of our 2021 Subordinated Notes, $94.2 million aggregate principal amount of our 5½% Senior Subordinated Notes due 2022 and $68.5 million aggregate principal amount of our 4⅝% Senior Subordinated Notes due 2023. In accordance with FASC 470-60, the exchange was accounted for as a troubled debt restructuring due to the level of concession provided by our senior subordinated note holders. Under this guidance, future interest applicable to the new 2022 Senior Secured Notes and 2023 Convertible Senior Notes was recorded as debt up to the point that the principal and future interest of the new notes was equal to the principal amount of the extinguished notes, rather than recognizing a gain on extinguishment for this amount. In May 2018, the debt principal balance and future interest applicable to the 2023 Convertible Senior Notes were reclassified to “Paid-in capital in excess of par” and “Common stock” in our Unaudited Condensed Consolidated Balance Sheets following the conversion of the notes into shares of Denbury common stock (see Conversions of 2023 and 2024 Convertible Senior Notes into Common Stock in May and June 2018 below for further discussion). As of September 30, 2018, $20.6 million of future interest on the new 2022 Senior Secured Notes was recorded as debt, which will be reduced as semiannual interest payments are made, with the remaining $3.3 million of future interest to be recognized as interest expense over the term of the notes. Therefore, future interest expense reflected in our Unaudited Condensed Consolidated Statements of Operations on the new 2022 Senior Secured Notes will be significantly lower than the actual cash interest payments. August 2018 Issuance of 7½% Senior Secured Second Lien Notes due 2024 In August 2018, we issued $450.0 million of 7½% Senior Secured Second Lien Notes due 2024 (the “2024 Senior Secured Notes”). The 2024 Senior Secured Notes, which bear interest at a rate of 7.50% per annum, were issued at par to repay outstanding borrowings on our Bank Credit Agreement, with additional proceeds used for general corporate purposes. The 2024 Senior Secured Notes mature on February 15, 2024, and interest is payable semiannually in arrears on February 15 and August 15 of each year, beginning in February 2019. We may redeem the 2024 Senior Secured Notes in whole or in part at our option beginning August 15, 2020, at a redemption price of 103.75% of the principal amount, and at declining redemption prices thereafter, as specified in the indenture governing the 2024 Senior Secured Notes. Prior to August 15, 2020, we may at our option redeem up to an aggregate of 35% of the principal amount of the 2024 Senior Secured Notes at a price of 107.50% of par with the proceeds of certain equity offerings. In addition, at any time prior to August 15, 2020, we may redeem the 2024 Senior Secured Notes in whole or in part at a price equal to 100% of the principal amount plus a “make-whole” premium and accrued and unpaid interest. The 2024 Senior Secured Notes are not subject to any sinking fund requirements. The 2024 Senior Secured Notes are guaranteed jointly and severally by our subsidiaries representing substantially all of our assets, operations and income and are secured by second-priority liens on substantially all of the assets that secure the Bank Credit Agreement, which second-priority liens are contractually subordinated to liens that secure our Bank Credit Agreement and any future additional priority lien debt. 9¼% Senior Secured Second Lien Notes due 2022 issued in January 2018 In January 2018, we issued $74.1 million of 2022 Senior Secured Notes, which principal amount is in addition to the $381.6 million of 2022 Senior Secured Notes issued during December 2017. All $455.7 million of the 2022 Senior Secured Notes were issued in connection with exchanges with a limited number of holders of the Company’s existing senior subordinated notes in December 2017 and January 2018 (see January 2018 Note Exchanges above). The 2022 Senior Secured Notes bear interest at 9.25% per annum, with interest payable semiannually in arrears on March 31 and September 30 of each year, and mature on March 31, 2022.  We may redeem the 2022 Senior Secured Notes in whole or in part at our option beginning March 31, 2019, at a redemption price of 109.25% of the principal amount, and at declining redemption prices thereafter, as specified in the indenture governing the 2022 Senior Secured Notes.  Prior to March 31, 2019, we may at our option redeem up to an aggregate of 35% of the principal amount of the 2022 Senior Secured Notes at a price of 109.25% of par with the proceeds of certain equity offerings.  In addition, at any time prior to March 31, 2019, we may redeem the 2022 Senior Secured Notes in whole or in part at a price equal to 100% of the principal amount plus a “make-whole” premium and accrued and unpaid interest.  The 2022 Senior Secured Notes are not subject to any sinking fund requirements. The 2022 Senior Secured Notes are guaranteed jointly and severally by our subsidiaries representing substantially all of our assets, operations and income and are secured by second-priority liens on substantially all of the assets that secure the Bank Credit Agreement, which second-priority liens are contractually subordinated to liens that secure our Bank Credit Agreement and any future additional priority lien debt. Conversions of 2023 and 2024 Convertible Senior Notes into Common Stock in May and June 2018 During the second quarter of 2018, holders of all $59.4 million aggregate principal amount outstanding of our 2023 Convertible Senior Notes and $84.7 million aggregate outstanding principal amount of our 2024 Convertible Senior Notes converted their notes into shares of Denbury common stock, at the rates specified in the indentures for these notes, resulting in the issuance of 55.2 million shares of our common stock upon conversion. The debt principal balances and future interest treated as debt applicable to the 2023 Convertible Senior Notes and 2024 Convertible Senior Notes, totaling $162.0 million, were reclassified to “Paid-in capital in excess of par” and “Common stock” in our Unaudited Condensed Consolidated Balance Sheets upon the conversion of the notes into shares of Denbury common stock. As of April 18, 2018 and May 30, 2018, there were no remaining 2024 Convertible Senior Notes and 2023 Convertible Senior Notes outstanding, respectively.

v3.10.0.1

Commodity Derivative Contracts	9 Months Ended
	Sep. 30, 2018
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Commodity Derivative Contracts	Note 5. Commodity Derivative Contracts We do not apply hedge accounting treatment to our oil and natural gas derivative contracts; therefore, the changes in the fair values of these instruments are recognized in income in the period of change.  These fair value changes, along with the settlements of expired contracts, are shown under “Commodity derivatives expense (income)” in our Unaudited Condensed Consolidated Statements of Operations. Historically, we have entered into various oil and natural gas derivative contracts to provide an economic hedge of our exposure to commodity price risk associated with anticipated future oil and natural gas production and to provide more certainty to our future cash flows. We do not hold or issue derivative financial instruments for trading purposes. Generally, these contracts have consisted of various combinations of price floors, collars, three-way collars, fixed-price swaps, fixed-price swaps enhanced with a sold put, and basis swaps. The production that we hedge has varied from year to year depending on our levels of debt, financial strength and expectation of future commodity prices. We manage and control market and counterparty credit risk through established internal control procedures that are reviewed on an ongoing basis.  We attempt to minimize credit risk exposure to counterparties through formal credit policies, monitoring procedures and diversification, and all of our commodity derivative contracts are with parties that are lenders under our Bank Credit Agreement (or affiliates of such lenders). As of September 30, 2018, all of our outstanding derivative contracts were subject to enforceable master netting arrangements whereby payables on those contracts can be offset against receivables from separate derivative contracts with the same counterparty. It is our policy to classify derivative assets and liabilities on a gross basis on our balance sheets, even if the contracts are subject to enforceable master netting arrangements. The following table summarizes our commodity derivative contracts as of September 30, 2018, none of which are classified as hedging instruments in accordance with the FASC Derivatives and Hedging topic: Months   Index Price   Volume (Barrels per day)   Contract Prices ($/Bbl) Range(1)   Weighted Average Price Swap   Sold Put   Floor   Ceiling Oil Contracts:                               2018 Fixed-Price Swaps                               Oct – Dec   NYMEX   20,500   $ 50.00 – 56.65   $ 51.69   $ —   $ —   $ — Oct – Dec   Argus LLS   5,000     60.10 – 60.25   60.18   —   —   — 2018 Three-Way Collars(2)                               Oct – Dec   NYMEX   15,000   $ 45.00 – 56.60   $ —   $ 36.50   $ 46.50   $ 53.88 2019 Fixed-Price Swaps                               Jan – June   NYMEX   3,500   $ 59.00 – 59.10   $ 59.05   $ —   $ —   $ — Jan - Dec   Argus LLS   4,000     69.10 – 74.90   71.40   —   —   — 2019 Three-Way Collars(2)                               Jan – June   NYMEX   18,500   $ 55.00 – 75.45   $ —   $ 48.84   $ 56.84   $ 69.94 July – Dec   NYMEX   22,000     55.00 – 75.45   —   48.55   56.55   69.17 Jan – Dec   Argus LLS   5,500     62.00 – 86.00   —   54.73   63.09   79.93 (1) Ranges presented for fixed-price swaps represent the lowest and highest fixed prices of all open contracts for the period presented. For three-way collars, ranges represent the lowest floor price and highest ceiling price for all open contracts for the period presented. (2) A three-way collar is a costless collar contract combined with a sold put feature (at a lower price) with the same counterparty. The value received for the sold put is used to enhance the contracted floor and ceiling price of the related collar. At the contract settlement date, (1) if the index price is higher than the ceiling price, we pay the counterparty the difference between the index price and ceiling price for the contracted volumes, (2) if the index price is between the floor and ceiling price, no settlements occur, (3) if the index price is lower than the floor price but at or above the sold put price, the counterparty pays us the difference between the index price and the floor price for the contracted volumes and (4) if the index price is lower than the sold put price, the counterparty pays us the difference between the floor price and the sold put price for the contracted volumes.

v3.10.0.1

Fair Value Measurements	9 Months Ended
	Sep. 30, 2018
Fair Value Disclosures [Abstract]
Fair Value Measurements	Note 6. Fair Value Measurements The FASC Fair Value Measurement topic defines fair value as the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date (often referred to as the “exit price”). We utilize market data or assumptions that market participants would use in pricing the asset or liability, including assumptions about risk and the risks inherent in the inputs to the valuation technique. These inputs can be readily observable, market corroborated or generally unobservable. We primarily apply the income approach for recurring fair value measurements and endeavor to utilize the best available information. Accordingly, we utilize valuation techniques that maximize the use of observable inputs and minimize the use of unobservable inputs. We are able to classify fair value balances based on the observability of those inputs. The FASC establishes a fair value hierarchy that prioritizes the inputs used to measure fair value. The hierarchy gives the highest priority to unadjusted quoted prices in active markets for identical assets or liabilities (Level 1 measurement) and the lowest priority to unobservable inputs (Level 3 measurement). The three levels of the fair value hierarchy are as follows: • Level 1 – Quoted prices in active markets for identical assets or liabilities as of the reporting date. • Level 2 – Pricing inputs are other than quoted prices in active markets included in Level 1, which are either directly or indirectly observable as of the reported date. Level 2 includes those financial instruments that are valued using models or other valuation methodologies. Instruments in this category include non-exchange-traded oil derivatives that are based on NYMEX pricing and fixed-price swaps that are based on regional pricing other than NYMEX (e.g., Light Louisiana Sweet). Our costless collars and the sold put features of our three-way collars are valued using the Black-Scholes model, an industry standard option valuation model that takes into account inputs such as contractual prices for the underlying instruments, maturity, quoted forward prices for commodities, interest rates, volatility factors and credit worthiness, as well as other relevant economic measures. Substantially all of these assumptions are observable in the marketplace throughout the full term of the instrument, can be derived from observable data or are supported by observable levels at which transactions are executed in the marketplace. • Level 3 – Pricing inputs include significant inputs that are generally less observable. These inputs may be used with internally developed methodologies that result in management’s best estimate of fair value. As of September 30, 2018, instruments in this category include non-exchange-traded three-way collars that are based on regional pricing other than NYMEX (e.g., Light Louisiana Sweet). The valuation models utilized for costless collars and three-way collars are consistent with the methodologies described above; however, the implied volatilities utilized in the valuation of Level 3 instruments are developed using a benchmark, which is considered a significant unobservable input. An increase or decrease of 100 basis points in the implied volatility inputs utilized in our fair value measurement would result in a change of approximately $400 thousand in the fair value of these instruments as of September 30, 2018. We adjust the valuations from the valuation model for nonperformance risk, using our estimate of the counterparty’s credit quality for asset positions and our credit quality for liability positions. We use multiple sources of third-party credit data in determining counterparty nonperformance risk, including credit default swaps. The following table sets forth, by level within the fair value hierarchy, our financial assets and liabilities that were accounted for at fair value on a recurring basis as of the periods indicated:     Fair Value Measurements Using: In thousands   Quoted Prices in Active Markets (Level 1)   Significant Other Observable Inputs (Level 2)   Significant Unobservable Inputs (Level 3)   Total September 30, 2018                 Liabilities                 Oil derivative contracts – current   $ —   $ (120,298 )   $ (5,056 )   $ (125,354 ) Oil derivative contracts – long-term   —   (12,214 )   (1,356 )   (13,570 ) Total Liabilities   $ —   $ (132,512 )   $ (6,412 )   $ (138,924 )                   December 31, 2017                 Liabilities                 Oil derivative contracts – current   $ —   $ (99,061 )   $ —   $ (99,061 ) Total Liabilities   $ —   $ (99,061 )   $ —   $ (99,061 ) Since we do not apply hedge accounting for our commodity derivative contracts, any gains and losses on our assets and liabilities are included in “Commodity derivatives expense (income)” in the accompanying Unaudited Condensed Consolidated Statements of Operations. Level 3 Fair Value Measurements The following table summarizes the changes in the fair value of our Level 3 assets and liabilities for the three and nine months ended September 30, 2018 and 2017:     Three Months Ended   Nine Months Ended     September 30,   September 30, In thousands   2018   2017   2018   2017 Fair value of Level 3 instruments, beginning of period   $ (1,168 )   $ 99   $ —   $ (526 ) Fair value gains (losses) on commodity derivatives   (5,244 )   (97 )   (6,412 )   528 Fair value of Level 3 instruments, end of period   $ (6,412 )   $ 2   $ (6,412 )   $ 2                   The amount of total gains (losses) for the period included in earnings attributable to the change in unrealized gains (losses) relating to assets or liabilities still held at the reporting date   $ (5,244 )   $ (71 )   $ (6,412 )   $ 54 We utilize an income approach to value our Level 3 costless collars and three-way collars. We obtain and ensure the appropriateness of the significant inputs to the calculation, including contractual prices for the underlying instruments, maturity, forward prices for commodities, interest rates, volatility factors and credit worthiness, and the fair value estimate is prepared and reviewed on a quarterly basis. The following table details fair value inputs related to implied volatilities utilized in the valuation of our Level 3 oil derivative contracts:     Fair Value at 9/30/2018 (in thousands)   Valuation Technique   Unobservable Input   Volatility Range Oil derivative contracts   $ (6,412 )   Discounted cash flow / Black-Scholes   Volatility of Light Louisiana Sweet for settlement periods beginning after September 30, 2018   20.7% – 29.9% Other Fair Value Measurements The carrying value of our loans under our Bank Credit Agreement approximate fair value, as they are subject to short-term floating interest rates that approximate the rates available to us for those periods. We use a market approach to determine the fair value of our fixed-rate long-term debt using observable market data. The fair values of our senior secured second lien notes, convertible senior notes, and senior subordinated notes are based on quoted market prices, which are considered Level 1 measurements under the fair value hierarchy. The estimated fair value of the principal amount of our debt as of September 30, 2018 and December 31, 2017, excluding pipeline financing and capital lease obligations, was $2,377.0 million and $2,260.6 million, respectively. We have other financial instruments consisting primarily of cash, cash equivalents, short-term receivables and payables that approximate fair value due to the nature of the instrument and the relatively short maturities.

v3.10.0.1

Commitments and Contingencies	9 Months Ended
	Sep. 30, 2018
Commitments and Contingencies Disclosure [Abstract]
Commitments and Contingencies	Note 7. Commitments and Contingencies Litigation We are involved in various lawsuits, claims and regulatory proceedings incidental to our businesses.  We are also subject to audits for various taxes (income, sales and use, and severance) in the various states in which we operate, and from time to time receive assessments for potential taxes that we may owe. While we currently believe that the ultimate outcome of these proceedings, individually and in the aggregate, will not have a material adverse effect on our financial position, results of operations or cash flows, litigation is subject to inherent uncertainties.  Although a single or multiple adverse rulings or settlements could possibly have a material adverse effect on our finances, we only accrue for losses from litigation and claims if we determine that a loss is probable and the amount can be reasonably estimated. Riley Ridge Helium Supply Contract Claim As part of our 2010 and 2011 acquisitions of the Riley Ridge Unit and associated gas processing facility that was under construction, the Company assumed a 20-year helium supply contract under which we agreed to supply the helium separated from the full well stream by operation of the gas processing facility to a third-party purchaser, APMTG Helium, LLC.  The helium supply contract provides for the delivery of a minimum contracted quantity of helium, subject to adjustment after startup of the Riley Ridge gas processing facility, with liquidated damages payable if specified quantities of helium are not supplied in accordance with the terms of the contract. The liquidated damages are specified in the contract at up to $8.0 million per contract year and are capped at an aggregate of $46.0 million over the term of the contract. As the gas processing facility has been shut-in since mid-2014, we have not been able to supply helium under the helium supply contract.  APMTG Helium, LLC filed a case in November 2014 in the Ninth Judicial District Court of Sublette County, Wyoming, claiming multiple years of liquidated damages for non-delivery of volumes of helium specified under the helium supply contract. The Company’s position is that our contractual obligations are excused by virtue of events that fall within the force majeure provisions in the helium supply contract. The evidentiary phase of the trial concluded on November 29, 2017. The parties submitted written closing briefs and rebuttal briefs to the District Court during February and April of 2018. We are currently awaiting a ruling from the District Court, and we are unable to predict at this time the outcome of this dispute.

v3.10.0.1

Subsequent Event	9 Months Ended
	Sep. 30, 2018
Subsequent Events [Abstract]
Subsequent Event	Note 8. Subsequent Event On October 28, 2018, the Company entered into a definitive merger agreement pursuant to which the Company will acquire Penn Virginia Corporation (NASDAQ: PVAC) (“Penn Virginia”). On the terms and subject to the conditions set forth in the merger agreement, each share of Penn Virginia common stock (“Penn Virginia Common Stock”), issued and outstanding immediately prior to the effective time of the merger (other than as described in the merger agreement) will be converted into the right to receive, at the election of the holder of such share of Penn Virginia Common Stock, either, (i) $25.86 in cash without interest and 12.4 shares of the Company’s common stock (“Denbury Common Stock”), (ii) $79.80 in cash without interest (the “Cash Election”), or (iii) 18.3454 shares of Denbury Common Stock (the “Stock Election”). The Cash and Stock Elections will be subject to proration to ensure that the total amount of cash paid to holders of Penn Virginia Common Stock is equal to $400 million. In the aggregate, $400 million in cash and approximately 191.8 million shares of Denbury Common Stock are expected to be paid as merger consideration. Consummation of the merger is subject to satisfaction of customary conditions.

v3.10.0.1

Basis of Presentation (Policies)	9 Months Ended
	Sep. 30, 2018
Accounting Policies [Abstract]
Organization and Nature of Operations	Organization and Nature of Operations Denbury Resources Inc., a Delaware corporation, is an independent oil and natural gas company with operations focused in two key operating areas: the Gulf Coast and Rocky Mountain regions.  Our goal is to increase the value of our properties through a combination of exploitation, drilling and proven engineering extraction practices, with the most significant emphasis relating to CO2 enhanced oil recovery operations.
Interim Financial Statements - Basis of Accounting, Policy	Interim Financial Statements The accompanying unaudited condensed consolidated financial statements of Denbury Resources Inc. and its subsidiaries have been prepared in accordance with the rules and regulations of the Securities and Exchange Commission (“SEC”) and do not include all of the information and footnotes required by accounting principles generally accepted in the United States for complete financial statements.  These financial statements and the notes thereto should be read in conjunction with our Annual Report on Form 10-K for the year ended December 31, 2017 (the “Form 10-K”).  Unless indicated otherwise or the context requires, the terms “we,” “our,” “us,” “Company” or “Denbury,” refer to Denbury Resources Inc. and its subsidiaries.
Interim Financial Statements - Use of Estimates	Accounting measurements at interim dates inherently involve greater reliance on estimates than at year end, and the results of operations for the interim periods shown in this report are not necessarily indicative of results to be expected for the year.  In management’s opinion, the accompanying unaudited condensed consolidated financial statements include all adjustments of a normal recurring nature necessary for a fair statement of our consolidated financial position as of September 30, 2018, our consolidated results of operations for the three and nine months ended September 30, 2018 and 2017, our consolidated cash flows for the nine months ended September 30, 2018 and 2017, and our consolidated statement of changes in stockholders’ equity for the nine months ended September 30, 2018.
Reclassifications	Reclassifications Certain prior period amounts have been reclassified to conform to the current year presentation. Such reclassifications had no impact on our reported net income, current assets, total assets, current liabilities, total liabilities or stockholders’ equity.
Cash, Cash Equivalents, and Restricted Cash	The following table provides a reconciliation of cash, cash equivalents, and restricted cash as reported within the Unaudited Condensed Consolidated Balance Sheets to “Cash, cash equivalents, and restricted cash at end of period” as reported within the Unaudited Condensed Consolidated Statements of Cash Flows: In thousands   September 30, 2018   December 31, 2017 Cash and cash equivalents   $ 66,711   $ 58 Restricted cash included in Other assets   16,272   15,934 Total cash, cash equivalents, and restricted cash shown in the Unaudited Condensed Consolidated Statements of Cash Flows   $ 82,983   $ 15,992 Amounts included in restricted cash included in “Other assets” in the accompanying Unaudited Condensed Consolidated Balance Sheets represent escrow accounts that are legally restricted for certain of our asset retirement obligations.
Net Income per Common Share	Net Income per Common Share Basic net income per common share is computed by dividing the net income attributable to common stockholders by the weighted average number of shares of common stock outstanding during the period.  Diluted net income per common share is calculated in the same manner, but includes the impact of potentially dilutive securities.  Potentially dilutive securities consist of nonvested restricted stock, nonvested performance-based equity awards, and shares into which our previously-outstanding convertible senior notes were convertible. The following table sets forth the reconciliations of net income and weighted average shares used for purposes of calculating the basic and diluted net income per common share for the periods indicated:     Three Months Ended   Nine Months Ended     September 30,   September 30, In thousands   2018   2017   2018   2017 Numerator                 Net income – basic   $ 78,419   $ 442   $ 148,219   $ 36,371 Effect of potentially dilutive securities                 Interest on convertible senior notes   —   —   538   — Net income – diluted   $ 78,419   $ 442   $ 148,757   $ 36,371                   Denominator                 Weighted average common shares outstanding – basic   451,256   392,013   426,036   390,448 Effect of potentially dilutive securities                 Restricted stock and performance-based equity awards   7,194   1,010   6,983   2,177 Convertible senior notes   —   —   22,915   — Weighted average common shares outstanding – diluted   458,450   393,023   455,934   392,625 Basic weighted average common shares exclude shares of nonvested restricted stock. As these restricted shares vest, they will be included in the shares outstanding used to calculate basic net income per common share (although time-vesting restricted stock is issued and outstanding upon grant). For purposes of calculating diluted weighted average common shares during the three and nine months ended September 30, 2018 and 2017, the nonvested restricted stock and performance-based equity awards are included in the computation using the treasury stock method, with the deemed proceeds equal to the average unrecognized compensation during the period, and for the shares underlying the previously-outstanding convertible senior notes as if the convertible senior notes were converted at the beginning of the 2018 period. In April and May 2018, all outstanding convertible senior notes converted into shares of Denbury common stock, resulting in the issuance of 55.2 million shares of our common stock upon conversion. These shares have been included in basic weighted average common shares outstanding beginning on the date of conversion. See Note 4, Long-Term Debt, for further discussion. The following securities could potentially dilute earnings per share in the future, but were excluded from the computation of diluted net income per share, as their effect would have been antidilutive:     Three Months Ended   Nine Months Ended     September 30,   September 30, In thousands   2018   2017   2018   2017 Stock appreciation rights   2,689   4,551   2,824   4,793 Restricted stock and performance-based equity awards   —   9,891   203   6,259
Recent Accounting Pronouncements	Recent Accounting Pronouncements Recently Adopted Cash Flows. In November 2016, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update (“ASU”) 2016-18, Statement of Cash Flows (“ASU 2016-18”). ASU 2016-18 addresses the diversity that exists in the classification and presentation of changes in restricted cash on the statement of cash flows, and requires that a statement of cash flows explain the change in total cash, cash equivalents, and amounts generally described as restricted cash or restricted cash equivalents. Therefore, entities will no longer present transfers between cash and cash equivalents and restricted cash and restricted cash equivalents in the statement of cash flows. Effective January 1, 2018, we adopted ASU 2016-18, which has been applied retrospectively for all comparative periods presented. Accordingly, restricted cash associated with our escrow accounts of $15.9 million and $15.4 million for the nine-month periods ended September 30, 2018 and 2017, respectively, have been included in “Cash, cash equivalents, and restricted cash at beginning of period” on our Unaudited Condensed Consolidated Statements of Cash Flows and $15.6 million included in “Cash, cash equivalents, and restricted cash at end of period” for the nine-month period ended September 30, 2017. The adoption of ASU 2016-18 did not have an impact on our consolidated balance sheets or results of operations. Our quarterly reports on Form 10-Q for the periods ended March 31, 2018 and June 30, 2018, filed with the SEC on May 10, 2018 and August 9, 2018, respectively, incorrectly included in the beginning-of-period and end-of-period balances of “Cash, cash equivalents, and restricted cash” in our Statements of Cash Flows, certain U.S. Treasury Notes held in escrow accounts legally restricted for use in certain of our asset retirement obligations. Under Financial Accounting Standards Board Codification (“FASC”) 230-10-20, these notes do not meet the definition of restricted cash and restricted cash equivalents due to their maturity date exceeding 90 days. Previously disclosed balances of these U.S. Treasury Notes of $24.6 million, $25.2 million and $25.4 million as of January 1, 2018 (the date of adoption), March 31, 2018 and June 30, 2018, respectively, should have been excluded from “Cash, cash equivalents, and restricted cash” on the Consolidated Statements of Cash Flows.  Accordingly, “Cash, cash equivalents, and restricted cash” as of January 1, 2018 (the date of adoption), March 31, 2018 and June 30, 2018, originally reported as $40.6 million, $40.9 million and $41.6 million, respectively, should have been reported as $16.0 million, $15.7 million and $16.2 million, respectively.  In addition, changes in the U.S. Treasury Notes of $0.6 million and $0.8 million during the three months ended March 31, 2018 and six months ended June 30, 2018, respectively, should have been included in net cash used in investing activities. Accordingly, net cash used in investing activities for the three months ended March 31, 2018, originally reported as $50.8 million, should have been $51.4 million, and net cash used in investing activities for the six months ended June 30, 2018, originally reported as $134.1 million, should have been $134.9 million. Management has evaluated the quantitative and qualitative impact of the error to previously issued unaudited consolidated statements of cash flows and concluded that the previously issued consolidated financial statements were not materially misstated.  However, management has elected to revise the unaudited consolidated statements of cash flows for each of the three months ended March 31, 2018 and six months ended June 30, 2018 in its future filings.  These revisions had no impact on the Company’s financial condition or results of operations for the periods presented. Revenue Recognition. In May 2014, the FASB issued ASU 2014-09, Revenue from Contracts with Customers (“ASU 2014-09”). ASU 2014-09 amends the guidance for revenue recognition to replace numerous, industry-specific requirements. The core principle of the ASU is that an entity should recognize revenue for the transfer of goods or services equal to the amount that it expects to be entitled to receive for those goods or services. The ASU implements a five-step process for customer contract revenue recognition that focuses on transfer of control, as opposed to transfer of risk and rewards. The amendment also requires enhanced disclosures regarding the nature, amount, timing and uncertainty of revenues and cash flows arising from contracts with customers. In March, April and May 2016, the FASB issued four additional ASUs which primarily clarified the implementation guidance on principal versus agent considerations, performance obligations and licensing, collectibility, presentation of sales taxes and other similar taxes collected from customers, and non-cash consideration. Effective January 1, 2018, we adopted ASU 2014-09 using the modified retrospective method. The adoption of ASU 2014-09 did not have an impact on our consolidated financial statements, but required enhanced footnote disclosures. See Note 2, Revenue Recognition, for additional information. Not Yet Adopted Fair Value Measurement. In August 2018, the FASB issued ASU 2018-13, Fair Value Measurement (Topic 820) – Disclosure Framework – Changes to the Disclosure Requirements for Fair Value Measurements (“ASU 2018-13”). ASU 2018-13 adds, modifies, or removes certain disclosure requirements for recurring and nonrecurring fair value measurements based on the FASB’s consideration of costs and benefits. The amendments in this ASU are effective for fiscal years beginning after December 15, 2019, and interim periods within those fiscal years, and early adoption is permitted. Entities must adopt the amendments on changes in unrealized gains and losses, the range and weighted average of significant unobservable inputs used to develop Level 3 fair value measurements, and the narrative description of measurement uncertainty prospectively, and all other amendments should be applied retrospectively to all periods presented. The adoption of ASU 2018-13 is currently not expected to have a material effect on our consolidated financial statements, but may require enhanced footnote disclosures. Leases. In February 2016, the FASB issued ASU 2016-02, Leases (“ASU 2016-02”). ASU 2016-02 amends the guidance for lease accounting to require lease assets and liabilities to be recognized on the balance sheet, along with additional disclosures regarding key leasing arrangements. The ASU does not apply to mineral leases or leases that convey the right to explore for or use the land on which oil, natural gas, and similar natural resources are contained. The amendments in this ASU are effective for fiscal years beginning after December 15, 2018, and interim periods within those fiscal years, and early adoption is permitted. Entities must adopt the standard using a modified retrospective transition and apply the guidance to the earliest comparative period presented, with certain practical expedients that entities may elect to apply. In January 2018, the FASB issued ASU 2018-01, Leases (Topic 842) – Land Easement Practical Expedient for Transition to Topic 842, which provides an optional practical expedient to existing or expired land easements that were not previously accounted for as leases under Topic 840, which permits a company to evaluate only new or modified land easements under the new guidance. We intend to elect the practical expedients provided in the new ASUs that allow historical lease classification of existing leases, allow entities to recognize leases with terms of one year or less in their statement of operations, and carry forward our accounting treatment for existing land easement agreements. We are currently evaluating our lease agreements and implementing a software system to summarize the key contract terms and financial information associated with each lease agreement, in order to assess the impact the adoption of ASU 2016-02 and ASU 2018-01 will have on our consolidated financial statements.
Revenue Recognition	We record revenue in accordance with FASC Topic 606, Revenue from Contracts with Customers, which we adopted on January 1, 2018, and applied to all existing contracts using the modified retrospective method. The core principle of FASC Topic 606 is that an entity should recognize revenue for the transfer of goods or services equal to the amount of consideration that it expects to be entitled to receive for those goods or services. This principle is achieved through applying a five-step process for customer contract revenue recognition: •Identify the contract or contracts with a customer – We derive the majority of our revenues from oil and natural gas sales contracts and CO2 sales and transportation contracts. The contracts specify each party’s rights regarding the goods or services to be transferred and contain commercial substance as they impact our financial statements. A high percentage of our receivables balance is current, and we have not historically entered into contracts with counterparties that pose a credit risk without requiring adequate economic protection to ensure collection. •Identify the performance obligations in the contract – Each of our revenue contracts specify a volume per day, or production from a lease designated in the contract (a distinct good), to be delivered at the delivery point over the term of the contract (the identified performance obligation). The customer takes delivery and physical possession of the product at the delivery point, which generally is also the point at which title transfers and the customer obtains the risks and rewards of ownership (the identified performance obligation is satisfied). •Determine the transaction price – Typically, our oil and natural gas contracts define the price as a formula price based on the average market price, as specified on set dates each month, for the specific commodity during the month of delivery. Certain of our CO2 contracts define the price as a fixed contractual price adjusted to an inflation index to reflect market pricing. Given the industry practice to invoice customers the month following the month of delivery and our high probability of collection of payment, no significant financing component is included in our contracts. •Allocate the transaction price to the performance obligations in the contract – The majority of our revenue contracts are short-term, with terms of one year or less, to which we have applied the practical expedient permitted under the standard eliminating the requirement to disclose the transaction price allocated to remaining performance obligations. In limited instances, we have revenue contracts with terms greater than one year; however, the future delivery volumes are wholly unsatisfied as they represent separate performance obligations with variable consideration. We utilized the practical expedient which eliminates the requirement to disclose the transaction price allocated to remaining performance obligations if the variable consideration is allocated entirely to wholly unsatisfied performance obligations. As there is only one performance obligation associated with our contracts, no allocation of the transaction price is necessary. •Recognize revenue when, or as, we satisfy a performance obligation – Once we have delivered the volume of commodity to the delivery point and the customer takes delivery and possession, we are entitled to payment and we invoice the customer for such delivered production. Payment under most oil and CO2 contracts is made within a month following product delivery and for natural gas and NGL contracts is generally made within two months following delivery. Timing of revenue recognition may differ from the timing of invoicing to customers; however, as the right to consideration after delivery is unconditional based on only the passage of time before payment of the consideration is due, upon delivery we record a receivable in “Accrued production receivable” in our Unaudited Condensed Consolidated Balance Sheets, which was $163.5 million and $146.3 million as of September 30, 2018 and December 31, 2017, respectively.
Commodity Derivative Contracts	We do not apply hedge accounting treatment to our oil and natural gas derivative contracts; therefore, the changes in the fair values of these instruments are recognized in income in the period of change.  These fair value changes, along with the settlements of expired contracts, are shown under “Commodity derivatives expense (income)” in our Unaudited Condensed Consolidated Statements of Operations. Historically, we have entered into various oil and natural gas derivative contracts to provide an economic hedge of our exposure to commodity price risk associated with anticipated future oil and natural gas production and to provide more certainty to our future cash flows. We do not hold or issue derivative financial instruments for trading purposes. Generally, these contracts have consisted of various combinations of price floors, collars, three-way collars, fixed-price swaps, fixed-price swaps enhanced with a sold put, and basis swaps. The production that we hedge has varied from year to year depending on our levels of debt, financial strength and expectation of future commodity prices. We manage and control market and counterparty credit risk through established internal control procedures that are reviewed on an ongoing basis.  We attempt to minimize credit risk exposure to counterparties through formal credit policies, monitoring procedures and diversification, and all of our commodity derivative contracts are with parties that are lenders under our Bank Credit Agreement (or affiliates of such lenders). As of September 30, 2018, all of our outstanding derivative contracts were subject to enforceable master netting arrangements whereby payables on those contracts can be offset against receivables from separate derivative contracts with the same counterparty. It is our policy to classify derivative assets and liabilities on a gross basis on our balance sheets, even if the contracts are subject to enforceable master netting arrangements.
Fair Value Measurements	The FASC Fair Value Measurement topic defines fair value as the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date (often referred to as the “exit price”). We utilize market data or assumptions that market participants would use in pricing the asset or liability, including assumptions about risk and the risks inherent in the inputs to the valuation technique. These inputs can be readily observable, market corroborated or generally unobservable. We primarily apply the income approach for recurring fair value measurements and endeavor to utilize the best available information. Accordingly, we utilize valuation techniques that maximize the use of observable inputs and minimize the use of unobservable inputs. We are able to classify fair value balances based on the observability of those inputs. The FASC establishes a fair value hierarchy that prioritizes the inputs used to measure fair value. The hierarchy gives the highest priority to unadjusted quoted prices in active markets for identical assets or liabilities (Level 1 measurement) and the lowest priority to unobservable inputs (Level 3 measurement). The three levels of the fair value hierarchy are as follows: • Level 1 – Quoted prices in active markets for identical assets or liabilities as of the reporting date. • Level 2 – Pricing inputs are other than quoted prices in active markets included in Level 1, which are either directly or indirectly observable as of the reported date. Level 2 includes those financial instruments that are valued using models or other valuation methodologies. Instruments in this category include non-exchange-traded oil derivatives that are based on NYMEX pricing and fixed-price swaps that are based on regional pricing other than NYMEX (e.g., Light Louisiana Sweet). Our costless collars and the sold put features of our three-way collars are valued using the Black-Scholes model, an industry standard option valuation model that takes into account inputs such as contractual prices for the underlying instruments, maturity, quoted forward prices for commodities, interest rates, volatility factors and credit worthiness, as well as other relevant economic measures. Substantially all of these assumptions are observable in the marketplace throughout the full term of the instrument, can be derived from observable data or are supported by observable levels at which transactions are executed in the marketplace. • Level 3 – Pricing inputs include significant inputs that are generally less observable. These inputs may be used with internally developed methodologies that result in management’s best estimate of fair value. As of September 30, 2018, instruments in this category include non-exchange-traded three-way collars that are based on regional pricing other than NYMEX (e.g., Light Louisiana Sweet). The valuation models utilized for costless collars and three-way collars are consistent with the methodologies described above; however, the implied volatilities utilized in the valuation of Level 3 instruments are developed using a benchmark, which is considered a significant unobservable input. An increase or decrease of 100 basis points in the implied volatility inputs utilized in our fair value measurement would result in a change of approximately $400 thousand in the fair value of these instruments as of September 30, 2018. We adjust the valuations from the valuation model for nonperformance risk, using our estimate of the counterparty’s credit quality for asset positions and our credit quality for liability positions. We use multiple sources of third-party credit data in determining counterparty nonperformance risk, including credit default swaps.

v3.10.0.1

Basis of Presentation (Tables)	9 Months Ended
	Sep. 30, 2018
Accounting Policies [Abstract]
Schedule of cash, cash equivalents, and restricted cash	The following table provides a reconciliation of cash, cash equivalents, and restricted cash as reported within the Unaudited Condensed Consolidated Balance Sheets to “Cash, cash equivalents, and restricted cash at end of period” as reported within the Unaudited Condensed Consolidated Statements of Cash Flows: In thousands   September 30, 2018   December 31, 2017 Cash and cash equivalents   $ 66,711   $ 58 Restricted cash included in Other assets   16,272   15,934 Total cash, cash equivalents, and restricted cash shown in the Unaudited Condensed Consolidated Statements of Cash Flows   $ 82,983   $ 15,992
Schedule of earnings per share, basic and diluted reconciliation	The following table sets forth the reconciliations of net income and weighted average shares used for purposes of calculating the basic and diluted net income per common share for the periods indicated:     Three Months Ended   Nine Months Ended     September 30,   September 30, In thousands   2018   2017   2018   2017 Numerator                 Net income – basic   $ 78,419   $ 442   $ 148,219   $ 36,371 Effect of potentially dilutive securities                 Interest on convertible senior notes   —   —   538   — Net income – diluted   $ 78,419   $ 442   $ 148,757   $ 36,371                   Denominator                 Weighted average common shares outstanding – basic   451,256   392,013   426,036   390,448 Effect of potentially dilutive securities                 Restricted stock and performance-based equity awards   7,194   1,010   6,983   2,177 Convertible senior notes   —   —   22,915   — Weighted average common shares outstanding – diluted   458,450   393,023   455,934   392,625
Schedule of Antidilutive Securities Excluded from Computation of Earnings Per Share	The following securities could potentially dilute earnings per share in the future, but were excluded from the computation of diluted net income per share, as their effect would have been antidilutive:     Three Months Ended   Nine Months Ended     September 30,   September 30, In thousands   2018   2017   2018   2017 Stock appreciation rights   2,689   4,551   2,824   4,793 Restricted stock and performance-based equity awards   —   9,891   203   6,259

v3.10.0.1

Revenue Recognition (Tables)	9 Months Ended
	Sep. 30, 2018
Revenue from Contract with Customer [Abstract]
Disaggregation of Revenue	The following table summarizes our revenues by product type for the three and nine months ended September 30, 2018 and 2017:     Three Months Ended   Nine Months Ended     September 30,   September 30, In thousands   2018   2017   2018   2017 Oil sales   $ 377,329   $ 256,621   $ 1,088,021   $ 768,912 Natural gas sales   2,299   2,409   7,193   7,176 CO2 sales and transportation fees   8,149   6,590   22,416   18,533 Total revenues   $ 387,777   $ 265,620   $ 1,117,630   $ 794,621

v3.10.0.1

Long-Term Debt (Tables)	9 Months Ended
	Sep. 30, 2018
Debt Disclosure [Abstract]
Components of Long-Term Debt	The table below reflects long-term debt and capital lease obligations outstanding as of the dates indicated:     September 30,   December 31, In thousands   2018   2017 Senior Secured Bank Credit Agreement   $ —   $ 475,000 9% Senior Secured Second Lien Notes due 2021   614,919   614,919 9¼% Senior Secured Second Lien Notes due 2022   455,668   381,568 7½% Senior Secured Second Lien Notes due 2024   450,000   — 3½% Convertible Senior Notes due 2024   —   84,650 6⅜% Senior Subordinated Notes due 2021   203,545   215,144 5½% Senior Subordinated Notes due 2022   314,662   408,882 4⅝% Senior Subordinated Notes due 2023   307,978   376,501 Pipeline financings   183,428   192,429 Capital lease obligations   11,290   26,298 Total debt principal balance   2,541,490   2,775,391 Future interest payable(1)   292,590   316,818 Debt issuance costs   (13,772 )   (7,935 ) Total debt, net of debt issuance costs   2,820,308   3,084,274 Less: current maturities of long-term debt(1)   (126,884 )   (105,188 ) Long-term debt and capital lease obligations   $ 2,693,424   $ 2,979,086 (1) Future interest payable represents most of the interest due over the terms of our 9% Senior Secured Second Lien Notes due 2021 (the “2021 Senior Secured Notes”), 9¼% Senior Secured Second Lien Notes due 2022 (the “2022 Senior Secured Notes”), and to a small extent our previously outstanding 3½% Convertible Senior Notes due 2024 (the “2024 Convertible Senior Notes”) and has been accounted for as debt in accordance with FASC 470-60, Troubled Debt Restructuring by Debtors. Our current maturities of long-term debt as of September 30, 2018 include $102.2 million of future interest payable related to the 2021 Senior Secured Notes and 2022 Senior Secured Notes that is due within the next twelve months. See January 2018 Note Exchanges below for further discussion.

v3.10.0.1

Commodity Derivative Contracts (Tables)	9 Months Ended
	Sep. 30, 2018
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Commodity derivative contracts not classified as hedging instruments	The following table summarizes our commodity derivative contracts as of September 30, 2018, none of which are classified as hedging instruments in accordance with the FASC Derivatives and Hedging topic: Months   Index Price   Volume (Barrels per day)   Contract Prices ($/Bbl) Range(1)   Weighted Average Price Swap   Sold Put   Floor   Ceiling Oil Contracts:                               2018 Fixed-Price Swaps                               Oct – Dec   NYMEX   20,500   $ 50.00 – 56.65   $ 51.69   $ —   $ —   $ — Oct – Dec   Argus LLS   5,000     60.10 – 60.25   60.18   —   —   — 2018 Three-Way Collars(2)                               Oct – Dec   NYMEX   15,000   $ 45.00 – 56.60   $ —   $ 36.50   $ 46.50   $ 53.88 2019 Fixed-Price Swaps                               Jan – June   NYMEX   3,500   $ 59.00 – 59.10   $ 59.05   $ —   $ —   $ — Jan - Dec   Argus LLS   4,000     69.10 – 74.90   71.40   —   —   — 2019 Three-Way Collars(2)                               Jan – June   NYMEX   18,500   $ 55.00 – 75.45   $ —   $ 48.84   $ 56.84   $ 69.94 July – Dec   NYMEX   22,000     55.00 – 75.45   —   48.55   56.55   69.17 Jan – Dec   Argus LLS   5,500     62.00 – 86.00   —   54.73   63.09   79.93 (1) Ranges presented for fixed-price swaps represent the lowest and highest fixed prices of all open contracts for the period presented. For three-way collars, ranges represent the lowest floor price and highest ceiling price for all open contracts for the period presented. (2) A three-way collar is a costless collar contract combined with a sold put feature (at a lower price) with the same counterparty. The value received for the sold put is used to enhance the contracted floor and ceiling price of the related collar. At the contract settlement date, (1) if the index price is higher than the ceiling price, we pay the counterparty the difference between the index price and ceiling price for the contracted volumes, (2) if the index price is between the floor and ceiling price, no settlements occur, (3) if the index price is lower than the floor price but at or above the sold put price, the counterparty pays us the difference between the index price and the floor price for the contracted volumes and (4) if the index price is lower than the sold put price, the counterparty pays us the difference between the floor price and the sold put price for the contracted volumes.

v3.10.0.1

Fair Value Measurements (Tables)	9 Months Ended
	Sep. 30, 2018
Fair Value Disclosures [Abstract]
Fair value hierarchy of financial assets and liabilities	The following table sets forth, by level within the fair value hierarchy, our financial assets and liabilities that were accounted for at fair value on a recurring basis as of the periods indicated:     Fair Value Measurements Using: In thousands   Quoted Prices in Active Markets (Level 1)   Significant Other Observable Inputs (Level 2)   Significant Unobservable Inputs (Level 3)   Total September 30, 2018                 Liabilities                 Oil derivative contracts – current   $ —   $ (120,298 )   $ (5,056 )   $ (125,354 ) Oil derivative contracts – long-term   —   (12,214 )   (1,356 )   (13,570 ) Total Liabilities   $ —   $ (132,512 )   $ (6,412 )   $ (138,924 )                   December 31, 2017                 Liabilities                 Oil derivative contracts – current   $ —   $ (99,061 )   $ —   $ (99,061 ) Total Liabilities   $ —   $ (99,061 )   $ —   $ (99,061 )
Changes in fair value of Level 3 assets and liabilities	The following table summarizes the changes in the fair value of our Level 3 assets and liabilities for the three and nine months ended September 30, 2018 and 2017:     Three Months Ended   Nine Months Ended     September 30,   September 30, In thousands   2018   2017   2018   2017 Fair value of Level 3 instruments, beginning of period   $ (1,168 )   $ 99   $ —   $ (526 ) Fair value gains (losses) on commodity derivatives   (5,244 )   (97 )   (6,412 )   528 Fair value of Level 3 instruments, end of period   $ (6,412 )   $ 2   $ (6,412 )   $ 2                   The amount of total gains (losses) for the period included in earnings attributable to the change in unrealized gains (losses) relating to assets or liabilities still held at the reporting date   $ (5,244 )   $ (71 )   $ (6,412 )   $ 54
Qualitative valuation techniques for assets and liabilities measured on a recurring basis (Level 3)	The following table details fair value inputs related to implied volatilities utilized in the valuation of our Level 3 oil derivative contracts:     Fair Value at 9/30/2018 (in thousands)   Valuation Technique   Unobservable Input   Volatility Range Oil derivative contracts   $ (6,412 )   Discounted cash flow / Black-Scholes   Volatility of Light Louisiana Sweet for settlement periods beginning after September 30, 2018   20.7% – 29.9%

v3.10.0.1

Basis of Presentation Basis of Presentation (Cash, Cash Equivalents, and Restricted Cash) (Details) - USD ($) $ in Thousands	Sep. 30, 2018	Jun. 30, 2018	Mar. 31, 2018	Jan. 01, 2018	Dec. 31, 2017	Sep. 30, 2017	Dec. 31, 2016
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents [Abstract]
Cash and cash equivalents	$ 66,711				$ 58
Restricted cash included in Other assets	16,272				15,934	$ 15,600	$ 15,400
Total cash, cash equivalents, and restricted cash shown in the unaudited condensed consolidated statement of cash flows	$ 82,983	$ 16,200	$ 15,700	$ 16,000	$ 15,992	$ 15,698	$ 17,050

v3.10.0.1

Basis of Presentation (Reconciliation of Weighted Average Shares Table) (Details) - USD ($) shares in Thousands, $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 2017
Numerator
Net income - basic	$ 78,419	$ 442	$ 148,219	$ 36,371
Interest on convertible senior notes	0	0	538	0
Net income - diluted	$ 78,419	$ 442	$ 148,757	$ 36,371
Denominator
Weighted average common shares outstanding - basic	451,256	392,013	426,036	390,448
Restricted stock and performance-based equity awards	7,194	1,010	6,983	2,177
Convertible senior notes	0	0	22,915	0
Weighted average common shares outstanding - diluted	458,450	393,023	455,934	392,625

v3.10.0.1

Basis of Presentation (Antidilutive Securities) (Details) - shares shares in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 2017
Stock appreciation rights
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Antidilutive Securities Excluded from Computation of Earnings Per Share, Amount	2,689	4,551	2,824	4,793
Restricted stock and performance-based equity awards
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Antidilutive Securities Excluded from Computation of Earnings Per Share, Amount	0	9,891	203	6,259

v3.10.0.1

Basis of Presentation Basis of Presentation (Details Textuals) - USD ($) $ in Thousands, shares in Millions	2 Months Ended	3 Months Ended	6 Months Ended
	May 31, 2018	Mar. 31, 2018	Jun. 30, 2018	Sep. 30, 2018	Jan. 01, 2018	Dec. 31, 2017	Sep. 30, 2017	Dec. 31, 2016
Accounting Policies [Abstract]
Restricted cash				$ 16,272		$ 15,934	$ 15,600	$ 15,400
Debt Conversion, Converted Instrument, Shares Issued	55.2
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents		$ 15,700	$ 16,200	$ 82,983	$ 16,000	$ 15,992	$ 15,698	$ 17,050
Net Cash Used in Investing Activities		51,400	134,900
Previously Reported
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents		40,900	41,600		40,600
Net Cash Used in Investing Activities		50,800	134,100
Adjustments
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents		(25,200)	(25,400)		$ (24,600)
Net Cash Used in Investing Activities		$ (600)	$ (800)

v3.10.0.1

Revenue Recognition (Disaggregation of Revenue) (Details) - USD ($)	3 Months Ended		9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 2017
Disaggregation of Revenue [Line Items]
Revenues and other income	$ 387,777,000	$ 265,620,000	$ 1,117,630,000	$ 794,621,000
Oil sales
Disaggregation of Revenue [Line Items]
Revenues and other income	377,329,000	256,621,000	1,088,021,000	768,912,000
Natural gas sales
Disaggregation of Revenue [Line Items]
Revenues and other income	2,299,000	2,409,000	7,193,000	7,176,000
CO2 sales and transportation fees
Disaggregation of Revenue [Line Items]
Revenues and other income	$ 8,149,000	$ 6,590,000	$ 22,416,000	$ 18,533,000

v3.10.0.1

Revenue Recognition (Details Textuals) - USD ($) $ in Thousands	Sep. 30, 2018	Dec. 31, 2017
Revenue from Contract with Customer [Abstract]
Accrued production receivable	$ 163,475	$ 146,334

v3.10.0.1

Assets Held for Sale (Details Textuals) $ in Millions	Sep. 30, 2018 USD ($)
Assets Held-for-sale, Not Part of Disposal Group [Abstract]
Land available for sale	$ 33.0

v3.10.0.1

Long-Term Debt (Components of Long-Term Debt) (Details) - USD ($) $ in Thousands		Sep. 30, 2018	Dec. 31, 2017
Debt Instrument [Line Items]
Senior Secured Bank Credit Agreement		$ 0	$ 475,000
Pipeline financings		183,428	192,429
Capital lease obligations		11,290	26,298
Total debt principal balance		2,541,490	2,775,391
Future interest payable	[1]	292,590	316,818
Debt issuance costs		(13,772)	(7,935)
Total debt, net of debt issuance costs		2,820,308	3,084,274
Less: current maturities of long-term debt	[1]	(126,884)	(105,188)
Long-term Debt and Capital Lease Obligations		2,693,424	2,979,086
9% Senior Secured Second Lien Notes Due 2021
Debt Instrument [Line Items]
Long-term Debt, Gross		$ 614,919	614,919
Debt Instrument, Interest Rate, Stated Percentage		9.00%
9 1/4% Senior Secured Second Lien Notes Due 2022
Debt Instrument [Line Items]
Long-term Debt, Gross		$ 455,668	381,568
Debt Instrument, Interest Rate, Stated Percentage		9.25%
7 1/2% Senior Secured Second Lien Notes due 2024 [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross		$ 450,000	0
Debt Instrument, Interest Rate, Stated Percentage		7.50%
3 1/2% Convertible Senior Notes Due 2024
Debt Instrument [Line Items]
Long-term Debt, Gross		$ 0	84,650
Debt Instrument, Interest Rate, Stated Percentage		3.50%
6 3/8% Senior Subordinated Notes due 2021
Debt Instrument [Line Items]
Long-term Debt, Gross		$ 203,545	215,144
Debt Instrument, Interest Rate, Stated Percentage		6.375%
5 1/2% Senior Subordinated Notes due 2022
Debt Instrument [Line Items]
Long-term Debt, Gross		$ 314,662	408,882
Debt Instrument, Interest Rate, Stated Percentage		5.50%
4 5/8% Senior Subordinated Notes due 2023
Debt Instrument [Line Items]
Long-term Debt, Gross		$ 307,978	376,501
Debt Instrument, Interest Rate, Stated Percentage		4.625%
Future interest payable on senior secured and convertible senior notes
Debt Instrument [Line Items]
Less: current maturities of long-term debt		$ (102,181)	(75,347)
Long-term Debt and Capital Lease Obligations		$ 190,410	$ 241,472
[1] Future interest payable represents most of the interest due over the terms of our 9% Senior Secured Second Lien Notes due 2021 (the “2021 Senior Secured Notes”), 9¼% Senior Secured Second Lien Notes due 2022 (the “2022 Senior Secured Notes”), and to a small extent our previously outstanding 3½% Convertible Senior Notes due 2024 (the “2024 Convertible Senior Notes”) and has been accounted for as debt in accordance with FASC 470-60, Troubled Debt Restructuring by Debtors. Our current maturities of long-term debt as of September 30, 2018 include $102.2 million of future interest payable related to the 2021 Senior Secured Notes and 2022 Senior Secured Notes that is due within the next twelve months. See January 2018 Note Exchanges below for further discussion.

v3.10.0.1

Long-Term Debt (Details Textuals)		1 Months Ended	2 Months Ended	3 Months Ended		9 Months Ended
		Jan. 31, 2018 USD ($)	Sep. 30, 2018 USD ($)	Sep. 30, 2018 USD ($)	Jun. 30, 2018 USD ($)	Sep. 30, 2018 USD ($) shares	Aug. 31, 2018 USD ($)	Aug. 13, 2018 USD ($)	May 30, 2018 USD ($)	Apr. 18, 2018 USD ($)	Dec. 31, 2017 USD ($)
Long Term Debt (Textuals) [Abstract]
Interest in guarantor subsidiaries			100.00%	100.00%		100.00%
Extinguishment of Debt, Amount		$ 40,800,000
Future interest payable on senior secured notes	[1]		$ 292,590,000	$ 292,590,000		$ 292,590,000					$ 316,818,000
Senior Secured Bank Credit Facility [Abstract]
Line of Credit Facility, Unused Capacity, Commitment Fee Percentage						0.50%
Line of Credit, Borrowing Base			615,000,000	615,000,000		$ 615,000,000		$ 1,050,000,000
Line of Credit Facility, Current Borrowing Capacity			615,000,000	$ 615,000,000		$ 615,000,000		1,050,000,000
Senior Secured Debt to Consolidated EBITDAX				2.5
Consolidated EBITDAX to Consolidated Interest Charges						1.25
Current Ratio Requirement						1.0
Long-term Line of Credit			0	$ 0		$ 0					475,000,000
Convertible Debt [Abstract]
Stock Issued During Period, Value, New Issues						162,004,000
Maximum Incurrence of Junior Lien Debt Permitted			$ 1,650,000,000	$ 1,650,000,000		$ 1,650,000,000		$ 1,200,000,000
Common Stock [Member]
Convertible Debt [Abstract]
Issued pursuant to notes conversion, shares | shares						55,249,955
Stock Issued During Period, Value, New Issues						$ 55,000
6 3/8% Senior Subordinated Notes due 2021
Long Term Debt (Textuals) [Abstract]
Debt Instrument, Interest Rate, Stated Percentage			6.375%	6.375%		6.375%
Debt Exchange, Amount		11,600,000
Long-term Debt, Gross			$ 203,545,000	$ 203,545,000		$ 203,545,000					215,144,000
5 1/2% Senior Subordinated Notes due 2022
Long Term Debt (Textuals) [Abstract]
Debt Instrument, Interest Rate, Stated Percentage			5.50%	5.50%		5.50%
Debt Exchange, Amount		94,200,000
Long-term Debt, Gross			$ 314,662,000	$ 314,662,000		$ 314,662,000					408,882,000
4 5/8% Senior Subordinated Notes due 2023
Long Term Debt (Textuals) [Abstract]
Debt Instrument, Interest Rate, Stated Percentage			4.625%	4.625%		4.625%
Debt Exchange, Amount		68,500,000
Long-term Debt, Gross			$ 307,978,000	$ 307,978,000		$ 307,978,000					376,501,000
9 1/4% Senior Secured Second Lien Notes Due 2022
Long Term Debt (Textuals) [Abstract]
Face value of notes		74,100,000									381,600,000
Debt Instrument, Interest Rate, Stated Percentage			9.25%	9.25%		9.25%
Long-term Debt, Gross			$ 455,668,000	$ 455,668,000		$ 455,668,000					381,568,000
5% Convertible Senior Notes Due 2023
Long Term Debt (Textuals) [Abstract]
Face value of notes		59,400,000
Convertible Debt [Abstract]
Debt Conversion, Original Debt, Amount					59,400,000
Convertible Debt									$ 0
3 1/2% Convertible Senior Notes Due 2024
Long Term Debt (Textuals) [Abstract]
Debt Instrument, Interest Rate, Stated Percentage			3.50%	3.50%		3.50%
Long-term Debt, Gross			$ 0	$ 0		$ 0					84,650,000
Convertible Debt [Abstract]
Debt Conversion, Original Debt, Amount					$ 84,700,000
Convertible Debt										$ 0
7 1/2% Senior Secured Second Lien Notes due 2024 [Member]
Long Term Debt (Textuals) [Abstract]
Face value of notes							$ 450,000,000
Debt Instrument, Interest Rate, Stated Percentage			7.50%	7.50%		7.50%
Long-term Debt, Gross			$ 450,000,000	$ 450,000,000		$ 450,000,000					$ 0
Year 2018 | Q3 [Member]
Senior Secured Bank Credit Facility [Abstract]
Total Debt to Consolidated EBITDAX			5.25
Year 2018 | Q4 [Member]
Senior Secured Bank Credit Facility [Abstract]
Total Debt to Consolidated EBITDAX			5.25
Year 2019
Senior Secured Bank Credit Facility [Abstract]
Total Debt to Consolidated EBITDAX			5.25
Year 2020 [Member]
Senior Secured Bank Credit Facility [Abstract]
Total Debt to Consolidated EBITDAX			5.25
Year 2021 [Member] | Q1 [Member]
Senior Secured Bank Credit Facility [Abstract]
Total Debt to Consolidated EBITDAX			4.50
Year 2021 [Member] | Q2 [Member]
Senior Secured Bank Credit Facility [Abstract]
Total Debt to Consolidated EBITDAX			4.50
Year 2021 [Member] | Q3 [Member]
Senior Secured Bank Credit Facility [Abstract]
Total Debt to Consolidated EBITDAX			4.50
Debt Instrument, Redemption, Period One | 9 1/4% Senior Secured Second Lien Notes Due 2022
Long Term Debt (Textuals) [Abstract]
Debt Instrument, Redemption Price, Percentage				109.25%
Debt Instrument, Redemption, Period One | 7 1/2% Senior Secured Second Lien Notes due 2024 [Member]
Long Term Debt (Textuals) [Abstract]
Debt Instrument, Redemption Price, Percentage				103.75%
Initial Redemption Period With Proceeds From Equity Offering Member | 9 1/4% Senior Secured Second Lien Notes Due 2022
Long Term Debt (Textuals) [Abstract]
Debt Instrument, Redemption Price, Percentage				109.25%
Debt Instrument, Percentage of Principal Amount Available To Be Redeemed				35.00%
Initial Redemption Period With Proceeds From Equity Offering Member | 7 1/2% Senior Secured Second Lien Notes due 2024 [Member]
Long Term Debt (Textuals) [Abstract]
Debt Instrument, Redemption Price, Percentage				107.50%
Debt Instrument, Percentage of Principal Amount Available To Be Redeemed				35.00%
Initial Redemption Period With Make Whole Premium | 9 1/4% Senior Secured Second Lien Notes Due 2022
Long Term Debt (Textuals) [Abstract]
Debt Instrument, Redemption Price, Percentage				100.00%
Initial Redemption Period With Make Whole Premium | 7 1/2% Senior Secured Second Lien Notes due 2024 [Member]
Long Term Debt (Textuals) [Abstract]
Debt Instrument, Redemption Price, Percentage				100.00%
Senior Subordinated Notes
Long Term Debt (Textuals) [Abstract]
Debt Exchange, Amount		$ 174,300,000
Notes Exchange
Long Term Debt (Textuals) [Abstract]
Future interest payable on senior secured notes			$ 20,600,000	$ 20,600,000		20,600,000
Interest Payable			$ 3,300,000	$ 3,300,000		$ 3,300,000
[1] Future interest payable represents most of the interest due over the terms of our 9% Senior Secured Second Lien Notes due 2021 (the “2021 Senior Secured Notes”), 9¼% Senior Secured Second Lien Notes due 2022 (the “2022 Senior Secured Notes”), and to a small extent our previously outstanding 3½% Convertible Senior Notes due 2024 (the “2024 Convertible Senior Notes”) and has been accounted for as debt in accordance with FASC 470-60, Troubled Debt Restructuring by Debtors. Our current maturities of long-term debt as of September 30, 2018 include $102.2 million of future interest payable related to the 2021 Senior Secured Notes and 2022 Senior Secured Notes that is due within the next twelve months. See January 2018 Note Exchanges below for further discussion.

v3.10.0.1

Commodity Derivative Contracts (Commodity Derivatives Outstanding Table) (Details)	Sep. 30, 2018 bbl / d $ / Barrel
Swap | Year 2018 | Q4 [Member] | NYMEX
Derivative [Line Items]
Volume per day | bbl / d	20,500
Weighted average swap price	51.69
Swap | Year 2018 | Q4 [Member] | NYMEX | Minimum
Derivative [Line Items]
Derivative, Swap Type, Fixed Price	50.00
Swap | Year 2018 | Q4 [Member] | NYMEX | Maximum
Derivative [Line Items]
Derivative, Swap Type, Fixed Price	56.65
Swap | Year 2018 | Q4 [Member] | LLS
Derivative [Line Items]
Volume per day | bbl / d	5,000
Weighted average swap price	60.18
Swap | Year 2018 | Q4 [Member] | LLS | Minimum
Derivative [Line Items]
Derivative, Swap Type, Fixed Price	60.10
Swap | Year 2018 | Q4 [Member] | LLS | Maximum
Derivative [Line Items]
Derivative, Swap Type, Fixed Price	60.25
Swap | Year 2019 | LLS
Derivative [Line Items]
Volume per day | bbl / d	4,000
Weighted average swap price	71.40
Swap | Year 2019 | LLS | Minimum
Derivative [Line Items]
Derivative, Swap Type, Fixed Price	69.10
Swap | Year 2019 | LLS | Maximum
Derivative [Line Items]
Derivative, Swap Type, Fixed Price	74.90
Swap | Year 2019 | Q1-Q2 | NYMEX
Derivative [Line Items]
Volume per day | bbl / d	3,500
Weighted average swap price	59.05
Swap | Year 2019 | Q1-Q2 | NYMEX | Minimum
Derivative [Line Items]
Derivative, Swap Type, Fixed Price	59.00
Swap | Year 2019 | Q1-Q2 | NYMEX | Maximum
Derivative [Line Items]
Derivative, Swap Type, Fixed Price	59.10
Three-way Collar | Year 2018 | Q4 [Member] | NYMEX
Derivative [Line Items]
Volume per day | bbl / d	15,000
Weighted average sold put price	36.50
Weighted average floor price	46.50
Weighted average ceiling price	53.88
Three-way Collar | Year 2018 | Q4 [Member] | NYMEX | Minimum
Derivative [Line Items]
Derivative, Floor Price	45.00
Three-way Collar | Year 2018 | Q4 [Member] | NYMEX | Maximum
Derivative [Line Items]
Derivative, Cap Price	56.60
Three-way Collar | Year 2019 | LLS
Derivative [Line Items]
Volume per day | bbl / d	5,500
Weighted average sold put price	54.73
Weighted average floor price	63.09
Weighted average ceiling price	79.93
Three-way Collar | Year 2019 | LLS | Minimum
Derivative [Line Items]
Derivative, Floor Price	62.00
Three-way Collar | Year 2019 | LLS | Maximum
Derivative [Line Items]
Derivative, Cap Price	86.00
Three-way Collar | Year 2019 | Q1-Q2 | NYMEX
Derivative [Line Items]
Volume per day | bbl / d	18,500
Weighted average sold put price	48.84
Weighted average floor price	56.84
Weighted average ceiling price	69.94
Three-way Collar | Year 2019 | Q1-Q2 | NYMEX | Minimum
Derivative [Line Items]
Derivative, Floor Price	55.00
Three-way Collar | Year 2019 | Q1-Q2 | NYMEX | Maximum
Derivative [Line Items]
Derivative, Cap Price	75.45
Three-way Collar | Year 2019 | Q3-Q4 | NYMEX
Derivative [Line Items]
Volume per day | bbl / d	22,000
Weighted average sold put price	48.55
Weighted average floor price	56.55
Weighted average ceiling price	69.17
Three-way Collar | Year 2019 | Q3-Q4 | NYMEX | Minimum
Derivative [Line Items]
Derivative, Floor Price	55.00
Three-way Collar | Year 2019 | Q3-Q4 | NYMEX | Maximum
Derivative [Line Items]
Derivative, Cap Price	75.45

v3.10.0.1

Fair Value Measurements (Fair Value Hierarchy Table) (Details) - USD ($) $ in Thousands	Sep. 30, 2018	Dec. 31, 2017
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Oil derivative contracts - current liability	$ (125,354)	$ (99,061)
Oil derivative contracts - long-term liabilities	(13,570)	0
Total Liabilities	(138,924)	(99,061)
Quoted Prices in Active Markets (Level 1)
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Oil derivative contracts - current liability	0	0
Oil derivative contracts - long-term liabilities	0
Total Liabilities	0	0
Significant Other Observable Inputs (Level 2)
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Oil derivative contracts - current liability	(120,298)	(99,061)
Oil derivative contracts - long-term liabilities	(12,214)
Total Liabilities	(132,512)	(99,061)
Significant Unobservable Inputs (Level 3)
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Oil derivative contracts - current liability	(5,056)	0
Oil derivative contracts - long-term liabilities	(1,356)
Total Liabilities	$ (6,412)	$ 0

v3.10.0.1

Fair Value Measurements (Level 3 Fair Value Measurements) (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 2017
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Fair value of Level 3 instruments, beginning of period	$ (1,168)	$ 99	$ 0	$ (526)
Fair value gains on commodity derivatives	(5,244)	(97)	(6,412)	528
Fair value of Level 3 instruments, end of period	(6,412)	2	(6,412)	2
The amount of total gains (losses) for the period included in earnings attributable to the change in unrealized gains (losses) relating to assets or liabilities still held at the reporting date	$ (5,244)	$ (71)	$ (6,412)	$ 54

v3.10.0.1

Fair Value Measurements Fair Value Measurements (Level 3 Valuation Techniques) (Details) - USD ($) $ in Thousands	9 Months Ended
	Sep. 30, 2018	Jun. 30, 2018	Dec. 31, 2017	Sep. 30, 2017	Jun. 30, 2017	Dec. 31, 2016
Fair Value Measurements, Recurring and nonrecurring, Valuation Techniques [Line Items]
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis with Unobservable Inputs	$ (6,412)	$ (1,168)	$ 0	$ 2	$ 99	$ (526)
Income Approach Valuation Technique
Fair Value Measurements, Recurring and nonrecurring, Valuation Techniques [Line Items]
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis with Unobservable Inputs	$ (6,412)
Income Approach Valuation Technique | Minimum
Fair Value Measurements, Recurring and nonrecurring, Valuation Techniques [Line Items]
Expected Volatility Range	20.70%
Income Approach Valuation Technique | Maximum
Fair Value Measurements, Recurring and nonrecurring, Valuation Techniques [Line Items]
Expected Volatility Range	29.90%

v3.10.0.1

Fair Value Measurements (Details Textuals) - USD ($) $ in Thousands	Sep. 30, 2018	Dec. 31, 2017
Fair Value Disclosures [Abstract]
Sensitivity Analysis of Fair Value, Impact of 100 Basis Point Increase or Decrease in Level 3 Inputs	$ 400
Debt, Fair Value	$ 2,377,000	$ 2,260,600

v3.10.0.1

Commitments and Contingencies (Details) - Helium Supply Arrangement [Member] $ in Millions	9 Months Ended
	Sep. 30, 2018 USD ($)
Long-term Purchase Commitment [Line Items]
Term of Long Term Supply Arrangement	20 years
Maximum Annual Payment In Event Of Shortfall	$ 8.0
Maximum Payment In Event Of Shortfall	$ 46.0

v3.10.0.1

Subsequent Event (Details Textuals) - Subsequent Event [Member]	Oct. 28, 2018 USD ($) $ / shares shares
Subsequent Event [Line Items]
Business Acquisition Cash Consideration | $	$ 400,000,000
Business Acquisition, Shares Issued	191,800,000
Stock and Cash Election [Member]
Subsequent Event [Line Items]
Business Acquisition, Share Price | $ / shares	$ 25.86
Number Of Shares To Be Received By Acquiree Company Shareholders On Acquisition	12.4
All Cash Election [Member]
Subsequent Event [Line Items]
Business Acquisition Cash Consideration | $	$ 79.80
All Stock Election [Member]
Subsequent Event [Line Items]
Number Of Shares To Be Received By Acquiree Company Shareholders On Acquisition	18.3454

This regulatory filing also includes additional resources:
dnr2018093010q.pdf