DNR Denbury Resources Inc

v3.20.1

Basis of Presentation (Policies)	3 Months Ended
	Mar. 31, 2020
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, 2019 (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 March 31, 2020, our consolidated results of operations for the three months ended March 31, 2020 and 2019, our consolidated cash flows for the three months ended March 31, 2020 and 2019, and our consolidated statements of changes in stockholders’ equity for the three months ended March 31, 2020 and 2019.
Reclassifications	Reclassifications Certain prior period amounts have been reclassified to conform to the current year presentation. On the Unaudited Condensed Consolidated Statements of Operations for the three months ended March 31, 2019, “Purchased oil sales” is a new line item and includes sales related to purchases of oil from third-parties, which were reclassified from “Other income,” “Purchased oil expenses” is a new line item and includes expenses related to purchases of oil from third-parties, which were reclassified from “Marketing and plant operating expenses” used in prior reports, and “Transportation and marketing expenses” is a new line item, previously captioned “Marketing and plant operating expenses,” but adjusted to exclude both expenses related to plant operating expenses, which were reclassified to “Other expenses,” and also purchases of oil from third-parties. Such reclassifications had no impact on our reported total revenues, expenses, net income, current assets, total assets, current liabilities, total liabilities or stockholders’ equity.
Cash, Cash Equivalents, and Restricted Cash	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   March 31, 2020   December 31, 2019 Cash and cash equivalents   $ 6,917   $ 516 Restricted cash included in other assets   32,657   32,529 Total cash, cash equivalents, and restricted cash shown in the Unaudited Condensed Consolidated Statements of Cash Flows   $ 39,574   $ 33,045 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 (Loss) per Common Share	Net Income (Loss) per Common Share Basic net income (loss) per common share is computed by dividing the net income (loss) attributable to common stockholders by the weighted average number of shares of common stock outstanding during the period.  Diluted net income (loss) 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 convertible senior notes are convertible. The following table sets forth the reconciliations of net income (loss) and weighted average shares used for purposes of calculating the basic and diluted net income (loss) per common share for the periods indicated:     Three Months Ended     March 31, In thousands   2020   2019 Numerator         Net income (loss) – basic   $ 74,016   $ (25,674 ) Effect of potentially dilutive securities         Interest on convertible senior notes including amortization of discount, net of tax   5,857   — Net income (loss) – diluted   $ 79,873   $ (25,674 )           Denominator         Weighted average common shares outstanding – basic   494,259   451,720 Effect of potentially dilutive securities         Restricted stock and performance-based equity awards   1,078   — Convertible senior notes(1)   90,853   — Weighted average common shares outstanding – diluted   586,190   451,720 (1) For the three months ended March 31, 2020, shares shown under “convertible senior notes” represent the impact over the period of the approximately 90.9 million shares of the Company’s common stock issuable upon full conversion of our convertible senior notes which were issued on June 19, 2019. 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 (loss) 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 months ended March 31, 2020, 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 convertible senior notes as if the convertible senior notes were converted at the beginning of the 2020 period. The following securities could potentially dilute earnings per share in the future, but were excluded from the computation of diluted net income (loss) per share, as their effect would have been antidilutive:     Three Months Ended     March 31, In thousands   2020   2019 Stock appreciation rights   1,528   2,091 Restricted stock and performance-based equity awards   14,007   8,350
Oil and Natural Gas Properties	Oil and Natural Gas Properties Unevaluated Costs. Under full cost accounting, we exclude certain unevaluated costs from the amortization base and full cost ceiling test pending the determination of whether proved reserves can be assigned to such properties. These costs are transferred to the full cost amortization base in the course of these properties being developed, tested and evaluated. At least annually, we test these assets for impairment based on an evaluation of management’s expectations of future pricing, evaluation of lease expiration terms, and planned project development activities. Given the significant recent declines in NYMEX oil prices to approximately $20 per Bbl in late March 2020 due to OPEC supply pressures and a reduction in worldwide oil demand amid the COVID-19 pandemic, as well as the uncertainty of future oil prices from demand destruction caused by the pandemic, we recognized an impairment of $244.9 million of our unevaluated costs during the three months ended March 31, 2020, whereby these costs were transferred to the full cost amortization base. Write-Down of Oil and Natural Gas Properties. The net capitalized costs of oil and natural gas properties are limited to the lower of unamortized cost or the cost center ceiling. The cost center ceiling is defined as (1) the present value of estimated future net revenues from proved oil and natural gas reserves before future abandonment costs (discounted at 10%), based on the average first-day-of-the-month oil and natural gas price for each month during a 12-month rolling period prior to the end of a particular reporting period; plus (2) the cost of properties not being amortized; plus (3) the lower of cost or estimated fair value of unproved properties included in the costs being amortized, if any; less (4) related income tax effects. Our future net revenues from proved oil and natural gas reserves are not reduced for development costs related to the cost of drilling for and developing CO2 reserves nor those related to the cost of constructing CO2 pipelines, as we do not have to incur additional costs to develop the proved oil and natural gas reserves. Therefore, we include in the ceiling test, as a reduction of future net revenues, that portion of our capitalized CO2 costs related to CO2 reserves and CO2 pipelines that we estimate will be consumed in the process of producing our proved oil and natural gas reserves. The fair value of our oil and natural gas derivative contracts is not included in the ceiling test, as we do not designate these contracts as hedge instruments for accounting purposes. The cost center ceiling test is prepared quarterly. We recognized a full cost pool ceiling test write-down of $72.5 million during the three months ended March 31, 2020, with first-day-of-the-month prices for the preceding 12 months averaging $55.17 per Bbl for crude oil and $1.68 per MMBtu for natural gas, after adjustments for market differentials by field. If oil prices were to remain at or near early-May 2020 levels in subsequent periods, we currently expect that we would also record significant write-downs in subsequent quarters, as the 12-month average price used in determining the full cost ceiling value will continue to decline during each rolling quarterly period in 2020.
Impairment Assessment of Long-Lived Assets	Impairment Assessment of Long-Lived Assets We test long-lived assets for impairment whenever events or changes in circumstances indicate that their carrying value may not be recoverable. These long-lived assets, which are not subject to our full cost pool ceiling test, are principally comprised of our capitalized CO2 properties and pipelines. Given the significant recent declines in NYMEX oil prices to approximately $20 per Bbl in late March 2020 due to OPEC supply pressures and a reduction in worldwide oil demand amid the COVID-19 pandemic, we performed a long-lived asset impairment test for our two long-lived asset groups (Gulf Coast region and Rocky Mountain region). We perform our long-lived asset impairment test by comparing the net carrying costs of our two long-lived asset groups to the respective expected future undiscounted net cash flows that are supported by these long-lived assets which include production of our probable and possible oil and natural gas reserves. The portion of our capitalized CO2 costs related to CO2 reserves and CO2 pipelines that we estimate will be consumed in the process of producing our proved oil and natural gas reserves is included in the full cost pool ceiling test as a reduction to future net revenues.  The remaining net capitalized costs that are not included in the full cost pool ceiling test, and related intangible assets, are subject to long-lived asset impairment testing. These costs totaled approximately $1.3 billion as of March 31, 2020. If the undiscounted net cash flows are below the net carrying costs for an asset group, we must record an impairment loss by the amount, if any, that net carrying costs exceed the fair value of the long-lived asset group. The undiscounted net cash flows for our asset groups exceeded the net carrying costs; thus, step two of the impairment test was not required and no impairment was recorded. Significant assumptions impacting expected future undiscounted net cash flows include projections of future oil and natural gas prices, projections of estimated quantities of oil and natural gas reserves, projections of future rates of production, timing and amount of future development and operating costs, projected availability and cost of CO2, projected recovery factors of tertiary reserves and risk-adjustment factors applied to the cash flows.
Recent Accounting Pronouncements	Recent Accounting Pronouncements Recently Adopted Financial Instruments – Credit Losses. In June 2016, the Financial Accounting Standards Board (“FASB”) issued ASU 2016-13, Financial Instruments – Credit Losses (“ASU 2016-13”). ASU 2016-13 changes the impairment model for most financial assets and certain other instruments, including trade and other receivables, and requires the use of a new forward-looking expected loss model that will result in the earlier recognition of allowances for losses. Effective January 1, 2020, we adopted ASU 2016-13. The implementation of this standard did not have a material impact on our consolidated financial statements. 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. Effective January 1, 2020, we adopted ASU 2018-13. The implementation of this standard did not have a material impact on our consolidated financial statements or footnote disclosures. Not Yet Adopted Reference Rate Reform. In March 2020, the FASB issued ASU 2020-04, Reference Rate Reform (Topic 848) (“ASU 2020-04”). ASU 2020-04 provides optional expedients and exceptions for applying GAAP to contracts, hedging relationships, and other transactions to ease financial reporting burdens related to the expected market transition from the London Interbank Offered Rate (“LIBOR”) or another reference rate to alternative reference rates. The amendments in this ASU are effective beginning on March 12, 2020, and an entity may elect to apply the amendments prospectively through December 31, 2022. We are currently evaluating the impact this guidance may have on our consolidated financial statements and related footnote disclosures. Income Taxes. In December 2019, the FASB issued ASU 2019-12, Income Taxes (Topic 740) – Simplifying the Accounting for Income Taxes (“ASU 2019-12”). The objective of ASU 2019-12 is to simplify the accounting for income taxes by removing certain exceptions to the general principles in Topic 740 and to provide more consistent application to improve the comparability of financial statements. The amendments in this ASU are effective for fiscal years beginning after December 15, 2020, and early adoption is permitted. We are currently evaluating the impact this guidance may have on our consolidated financial statements and related footnote disclosures.
Revenue Recognition	We record revenue in accordance with Financial Accounting Standards Board Codification (“FASC”) Topic 606, Revenue from Contracts with Customers. 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. 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 $72.5 million and $139.4 million as of March 31, 2020 and December 31, 2019, respectively. The Company enters into purchase transactions with third parties and separate sale transactions with third parties in the Gulf Coast region. Revenues and expenses from these transactions are presented on a gross basis, as we act as a principal in the transaction by assuming control of the commodities purchased and the responsibility to deliver the commodities sold. Revenue is recognized when control transfers to the purchaser at the delivery point based on the price received from the purchaser.
Income Taxes	We evaluate our estimated annual effective income tax rate based on current and forecasted business results and enacted tax laws on a quarterly basis and apply this tax rate to our ordinary income or loss to calculate our estimated tax liability or benefit. Our income taxes are based on an estimated statutory rate of approximately 25% in 2020 and 2019. Our effective tax rate for the three months ended March 31, 2020, differed from our estimated statutory rate, primarily due to tax changes enacted by the CARES Act which resulted in the full release of a $24.5 million valuation allowance against a portion of our business interest expense deduction that we previously estimated would be disallowed, offset by the establishment of a valuation allowance on a portion of our enhanced oil recovery credits that currently are not expected to be utilized.
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 March 31, 2020, 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 and 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 December 31, 2019, instruments in this category included non-exchange-traded three-way collars that were based on regional pricing other than NYMEX (e.g., Light Louisiana Sweet). The valuation models utilized for three-way collars were consistent with the methodologies described above; however, the implied volatilities utilized in the valuation of Level 3 instruments were developed using a benchmark, which was considered a significant unobservable input. 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.

v3.20.1

Commodity Derivative Contracts	3 Months Ended
	Mar. 31, 2020
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Commodity Derivative Contracts	Note 6. 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 March 31, 2020, 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 March 31, 2020, 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:                               2020 Fixed-Price Swaps                               Apr – Dec   NYMEX   13,500   $ 36.25 – 61.00   $ 40.52   $ —   $ —   $ — Apr – Dec   Argus LLS   7,500     35.00 – 64.26   51.67   —   —   — 2020 Three-Way Collars(2)                               Apr – June   NYMEX   11,500   $ 55.00 – 82.65   $ —   $ 47.95   $ 57.18   $ 63.44 Apr – June   Argus LLS   7,000     58.00 – 87.10   —   52.93   62.09   69.54 July – Dec   NYMEX   9,500     55.00 – 82.65   —   47.93   57.00   63.25 July – Dec   Argus LLS   5,000     58.00 – 87.10   —   52.80   61.63   70.35 (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 oil prices average less than the sold put price, our receipts on settlement would be limited to the difference between the floor price and the sold put price for the contracted volumes.

v3.20.1

Revenue Recognition (Details Textuals) - USD ($) $ in Thousands	Mar. 31, 2020	Dec. 31, 2019
Revenue from Contract with Customer [Abstract]
Accrued production receivable	$ 72,470	$ 139,407

v3.20.1

Commodity Derivative Contracts (Commodity Derivatives Outstanding Table) (Details)	Mar. 31, 2020 bbl / d $ / Barrel
Swap | Q2-Q4 | NYMEX
Derivative [Line Items]
Volume per day | bbl / d	13,500
Weighted average swap price	40.52
Swap | Q2-Q4 | NYMEX | Minimum
Derivative [Line Items]
Derivative, Swap Type, Fixed Price	36.25
Swap | Q2-Q4 | NYMEX | Maximum
Derivative [Line Items]
Derivative, Swap Type, Fixed Price	61.00
Swap | Q2-Q4 | Argus LLS
Derivative [Line Items]
Volume per day | bbl / d	7,500
Weighted average swap price	51.67
Swap | Q2-Q4 | Argus LLS | Minimum
Derivative [Line Items]
Derivative, Swap Type, Fixed Price	35.00
Swap | Q2-Q4 | Argus LLS | Maximum
Derivative [Line Items]
Derivative, Swap Type, Fixed Price	64.26
Three-way Collar | Q2 | NYMEX
Derivative [Line Items]
Volume per day | bbl / d	11,500
Weighted average sold put price	47.95
Weighted average floor price	57.18
Weighted average ceiling price	63.44
Three-way Collar | Q2 | NYMEX | Minimum
Derivative [Line Items]
Derivative, Floor Price	55.00
Three-way Collar | Q2 | NYMEX | Maximum
Derivative [Line Items]
Derivative, Cap Price	82.65
Three-way Collar | Q2 | Argus LLS
Derivative [Line Items]
Volume per day | bbl / d	7,000
Weighted average sold put price	52.93
Weighted average floor price	62.09
Weighted average ceiling price	69.54
Three-way Collar | Q2 | Argus LLS | Minimum
Derivative [Line Items]
Derivative, Floor Price	58.00
Three-way Collar | Q2 | Argus LLS | Maximum
Derivative [Line Items]
Derivative, Cap Price	87.10
Three-way Collar | Q3-Q4 | NYMEX
Derivative [Line Items]
Volume per day | bbl / d	9,500
Weighted average sold put price	47.93
Weighted average floor price	57.00
Weighted average ceiling price	63.25
Three-way Collar | Q3-Q4 | NYMEX | Minimum
Derivative [Line Items]
Derivative, Floor Price	55.00
Three-way Collar | Q3-Q4 | NYMEX | Maximum
Derivative [Line Items]
Derivative, Cap Price	82.65
Three-way Collar | Q3-Q4 | Argus LLS
Derivative [Line Items]
Volume per day | bbl / d	5,000
Weighted average sold put price	52.80
Weighted average floor price	61.63
Weighted average ceiling price	70.35
Three-way Collar | Q3-Q4 | Argus LLS | Minimum
Derivative [Line Items]
Derivative, Floor Price	58.00
Three-way Collar | Q3-Q4 | Argus LLS | Maximum
Derivative [Line Items]
Derivative, Cap Price	87.10

v3.20.1

Commitments and Contingencies (Helium Supply Arrangement) (Details) $ in Millions	3 Months Ended
	Mar. 31, 2020 USD ($)
Commitments and Contingencies Disclosure [Abstract]
Term of long term supply arrangement	20 years
Maximum payment in event of shortfall	$ 46.0

v3.20.1

Basis of Presentation	3 Months Ended
	Mar. 31, 2020
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, 2019 (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 March 31, 2020, our consolidated results of operations for the three months ended March 31, 2020 and 2019, our consolidated cash flows for the three months ended March 31, 2020 and 2019, and our consolidated statements of changes in stockholders’ equity for the three months ended March 31, 2020 and 2019. Risks and Uncertainties In March 2020, the World Health Organization declared the ongoing COVID-19 outbreak a pandemic, and the President of the United States declared the COVID-19 pandemic a national emergency. The COVID-19 pandemic has caused a rapid and precipitous drop in the worldwide demand for oil, which worsened an already deteriorated oil market that resulted from the early-March 2020 failure by the group of oil producing nations known as OPEC+ to reach an agreement over proposed oil production cuts. Although OPEC+ has subsequently reached an agreement to curtail production, it is estimated that the near-term impact on global oil demand is significantly greater than the magnitude of production curtailments, and storage centers in the United States and around the world could potentially reach maximum storage levels. Together, these events have caused oil prices to plummet since the first week of March 2020, which has continued, and is expected to significantly decrease our realized oil prices in the second quarter of 2020 and potentially beyond. Oil prices are expected to continue to be volatile as a result of these events and the ongoing COVID-19 outbreak, and as changes in oil inventories, oil demand and economic performance are reported. Because the realized oil prices we have received since early March 2020 have been significantly reduced, our operating cash flow and liquidity have been adversely affected. The extent of the impact on our operational and financial performance is dependent upon future developments that drive domestic and global oil supply and demand, including the duration and spread of the pandemic, its severity, the actions to contain the disease or mitigate its impact, related restrictions on travel, and future levels of domestic and global oil production. Industry Conditions, Liquidity, Management’s Plans, and Going Concern As discussed above, COVID-19 has had a significant impact on oil prices, which directly impacts our business in many ways. The decrease in oil prices directly impacts the operating cash flow we are able to generate from our production, and if prices are too low, it may not be economic for us to produce certain of our properties. The decrease in oil prices may also impact our other sources of liquidity, potentially reducing our borrowing capacity under our bank credit facility. Our primary sources of capital and liquidity are our cash flows from operations and availability of borrowing capacity under our bank credit facility. As of May 13, 2020, our bank credit facility availability was $520.3 million, based on a $615 million borrowing base and $94.7 million of letters of credit currently outstanding. Our most significant cash outlays relate to our development capital expenditures, current period operating expenses, and our debt service obligations. Our senior secured bank credit facility and the indentures related to our senior secured second lien notes, senior convertible notes, and senior subordinated notes are subject to a variety of covenants. Throughout 2019 and the three months ended March 31, 2020, we were in compliance with all covenants under our senior secured bank credit facility, including maintenance financial covenants, as well as covenants within our long-term note indentures. However, declining industry conditions and reductions in our cash flows and liquidity over the past few months have made our ability to comply with the maximum permitted ratio of total net debt to consolidated EBITDAX maintenance financial covenant in our senior secured bank credit facility increasingly unlikely if these conditions continue, and we foresee the potential to be in violation of this covenant by the end of the second or third quarter of this year. Our senior secured bank credit facility matures on December 9, 2021, provided that the maturity date may be accelerated to earlier dates in 2021 (February 12, 2021, May 14, 2021 or August 13, 2021) if certain defined liquidity ratios are not met, or if our 9% Senior Secured Second Lien Notes due May 15, 2021 (the “2021 Senior Secured Notes”) or our 6⅜% Senior Subordinated Notes due in August 2021 (the “2021 Senior Subordinated Notes”) are not repaid or refinanced by each of their respective maturity dates. Our maintenance financial covenants contained in our senior secured bank credit facility are described in Note 4, Long-Term Debt. In this low oil price environment and period of uncertainty, we have taken various steps to preserve our liquidity including (1) by reducing our 2020 budgeted development capital spending by 44% from initial levels and to less than half of 2019 levels, (2) by continuing to focus on reducing our operating and overhead costs, and (3) by restructuring certain of our three-way collars covering 14,500 barrels per day into fixed-price swaps for the second through fourth quarters of 2020 to increase downside protection against current and potential further declines in oil prices. As the ability to fund our full 2020 development capital budget with cash flow from operations and asset sale proceeds is dependent in part upon future commodity pricing, which we cannot predict nor control, we expect to fund any potential shortfall with incremental borrowings under our senior secured bank credit facility. There can be no assurances that we will be able to fund any potential shortfall with borrowings under our senior secured bank credit facility. Collectively, the above factors, along with the materially adverse change in industry market conditions and our cash flow over the past few months, have substantially diminished our ability to repay, refinance, or restructure our $584.7 million outstanding principal balance of 2021 Senior Secured Notes and have raised substantial doubt about our ability to continue as a going concern. Because the actions described above are not sufficient to significantly mitigate the substantial doubt about our ability to continue as a going concern over the next twelve months from the issuance of these financial statements, we have engaged advisors to assist with the evaluation of a range of strategic alternatives and are engaged in discussions with our lenders and bondholders regarding a potential comprehensive restructuring of our indebtedness. There can be no assurances that the Company will be able to successfully restructure its indebtedness, improve its financial position or complete any strategic transaction. The condensed consolidated financial statements included in this Quarterly Report on Form 10-Q have been prepared on a going concern basis of accounting, which contemplates continuity of operations, realization of assets, and satisfaction of liabilities and commitments in the normal course of business. The condensed consolidated financial statements do not reflect any adjustments that might result if we are unable to continue as a going concern. Reclassifications Certain prior period amounts have been reclassified to conform to the current year presentation. On the Unaudited Condensed Consolidated Statements of Operations for the three months ended March 31, 2019, “Purchased oil sales” is a new line item and includes sales related to purchases of oil from third-parties, which were reclassified from “Other income,” “Purchased oil expenses” is a new line item and includes expenses related to purchases of oil from third-parties, which were reclassified from “Marketing and plant operating expenses” used in prior reports, and “Transportation and marketing expenses” is a new line item, previously captioned “Marketing and plant operating expenses,” but adjusted to exclude both expenses related to plant operating expenses, which were reclassified to “Other expenses,” and also purchases of oil from third-parties. Such reclassifications had no impact on our reported total revenues, expenses, 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   March 31, 2020   December 31, 2019 Cash and cash equivalents   $ 6,917   $ 516 Restricted cash included in other assets   32,657   32,529 Total cash, cash equivalents, and restricted cash shown in the Unaudited Condensed Consolidated Statements of Cash Flows   $ 39,574   $ 33,045 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 (Loss) per Common Share Basic net income (loss) per common share is computed by dividing the net income (loss) attributable to common stockholders by the weighted average number of shares of common stock outstanding during the period.  Diluted net income (loss) 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 convertible senior notes are convertible. The following table sets forth the reconciliations of net income (loss) and weighted average shares used for purposes of calculating the basic and diluted net income (loss) per common share for the periods indicated:     Three Months Ended     March 31, In thousands   2020   2019 Numerator         Net income (loss) – basic   $ 74,016   $ (25,674 ) Effect of potentially dilutive securities         Interest on convertible senior notes including amortization of discount, net of tax   5,857   — Net income (loss) – diluted   $ 79,873   $ (25,674 )           Denominator         Weighted average common shares outstanding – basic   494,259   451,720 Effect of potentially dilutive securities         Restricted stock and performance-based equity awards   1,078   — Convertible senior notes(1)   90,853   — Weighted average common shares outstanding – diluted   586,190   451,720 (1) For the three months ended March 31, 2020, shares shown under “convertible senior notes” represent the impact over the period of the approximately 90.9 million shares of the Company’s common stock issuable upon full conversion of our convertible senior notes which were issued on June 19, 2019. 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 (loss) 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 months ended March 31, 2020, 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 convertible senior notes as if the convertible senior notes were converted at the beginning of the 2020 period. The following securities could potentially dilute earnings per share in the future, but were excluded from the computation of diluted net income (loss) per share, as their effect would have been antidilutive:     Three Months Ended     March 31, In thousands   2020   2019 Stock appreciation rights   1,528   2,091 Restricted stock and performance-based equity awards   14,007   8,350 Oil and Natural Gas Properties Unevaluated Costs. Under full cost accounting, we exclude certain unevaluated costs from the amortization base and full cost ceiling test pending the determination of whether proved reserves can be assigned to such properties. These costs are transferred to the full cost amortization base in the course of these properties being developed, tested and evaluated. At least annually, we test these assets for impairment based on an evaluation of management’s expectations of future pricing, evaluation of lease expiration terms, and planned project development activities. Given the significant recent declines in NYMEX oil prices to approximately $20 per Bbl in late March 2020 due to OPEC supply pressures and a reduction in worldwide oil demand amid the COVID-19 pandemic, as well as the uncertainty of future oil prices from demand destruction caused by the pandemic, we recognized an impairment of $244.9 million of our unevaluated costs during the three months ended March 31, 2020, whereby these costs were transferred to the full cost amortization base. Write-Down of Oil and Natural Gas Properties. The net capitalized costs of oil and natural gas properties are limited to the lower of unamortized cost or the cost center ceiling. The cost center ceiling is defined as (1) the present value of estimated future net revenues from proved oil and natural gas reserves before future abandonment costs (discounted at 10%), based on the average first-day-of-the-month oil and natural gas price for each month during a 12-month rolling period prior to the end of a particular reporting period; plus (2) the cost of properties not being amortized; plus (3) the lower of cost or estimated fair value of unproved properties included in the costs being amortized, if any; less (4) related income tax effects. Our future net revenues from proved oil and natural gas reserves are not reduced for development costs related to the cost of drilling for and developing CO2 reserves nor those related to the cost of constructing CO2 pipelines, as we do not have to incur additional costs to develop the proved oil and natural gas reserves. Therefore, we include in the ceiling test, as a reduction of future net revenues, that portion of our capitalized CO2 costs related to CO2 reserves and CO2 pipelines that we estimate will be consumed in the process of producing our proved oil and natural gas reserves. The fair value of our oil and natural gas derivative contracts is not included in the ceiling test, as we do not designate these contracts as hedge instruments for accounting purposes. The cost center ceiling test is prepared quarterly. We recognized a full cost pool ceiling test write-down of $72.5 million during the three months ended March 31, 2020, with first-day-of-the-month prices for the preceding 12 months averaging $55.17 per Bbl for crude oil and $1.68 per MMBtu for natural gas, after adjustments for market differentials by field. If oil prices were to remain at or near early-May 2020 levels in subsequent periods, we currently expect that we would also record significant write-downs in subsequent quarters, as the 12-month average price used in determining the full cost ceiling value will continue to decline during each rolling quarterly period in 2020. Impairment Assessment of Long-Lived Assets We test long-lived assets for impairment whenever events or changes in circumstances indicate that their carrying value may not be recoverable. These long-lived assets, which are not subject to our full cost pool ceiling test, are principally comprised of our capitalized CO2 properties and pipelines. Given the significant recent declines in NYMEX oil prices to approximately $20 per Bbl in late March 2020 due to OPEC supply pressures and a reduction in worldwide oil demand amid the COVID-19 pandemic, we performed a long-lived asset impairment test for our two long-lived asset groups (Gulf Coast region and Rocky Mountain region). We perform our long-lived asset impairment test by comparing the net carrying costs of our two long-lived asset groups to the respective expected future undiscounted net cash flows that are supported by these long-lived assets which include production of our probable and possible oil and natural gas reserves. The portion of our capitalized CO2 costs related to CO2 reserves and CO2 pipelines that we estimate will be consumed in the process of producing our proved oil and natural gas reserves is included in the full cost pool ceiling test as a reduction to future net revenues.  The remaining net capitalized costs that are not included in the full cost pool ceiling test, and related intangible assets, are subject to long-lived asset impairment testing. These costs totaled approximately $1.3 billion as of March 31, 2020. If the undiscounted net cash flows are below the net carrying costs for an asset group, we must record an impairment loss by the amount, if any, that net carrying costs exceed the fair value of the long-lived asset group. The undiscounted net cash flows for our asset groups exceeded the net carrying costs; thus, step two of the impairment test was not required and no impairment was recorded. Significant assumptions impacting expected future undiscounted net cash flows include projections of future oil and natural gas prices, projections of estimated quantities of oil and natural gas reserves, projections of future rates of production, timing and amount of future development and operating costs, projected availability and cost of CO2, projected recovery factors of tertiary reserves and risk-adjustment factors applied to the cash flows. Recent Accounting Pronouncements Recently Adopted Financial Instruments – Credit Losses. In June 2016, the Financial Accounting Standards Board (“FASB”) issued ASU 2016-13, Financial Instruments – Credit Losses (“ASU 2016-13”). ASU 2016-13 changes the impairment model for most financial assets and certain other instruments, including trade and other receivables, and requires the use of a new forward-looking expected loss model that will result in the earlier recognition of allowances for losses. Effective January 1, 2020, we adopted ASU 2016-13. The implementation of this standard did not have a material impact on our consolidated financial statements. 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. Effective January 1, 2020, we adopted ASU 2018-13. The implementation of this standard did not have a material impact on our consolidated financial statements or footnote disclosures. Not Yet Adopted Reference Rate Reform. In March 2020, the FASB issued ASU 2020-04, Reference Rate Reform (Topic 848) (“ASU 2020-04”). ASU 2020-04 provides optional expedients and exceptions for applying GAAP to contracts, hedging relationships, and other transactions to ease financial reporting burdens related to the expected market transition from the London Interbank Offered Rate (“LIBOR”) or another reference rate to alternative reference rates. The amendments in this ASU are effective beginning on March 12, 2020, and an entity may elect to apply the amendments prospectively through December 31, 2022. We are currently evaluating the impact this guidance may have on our consolidated financial statements and related footnote disclosures. Income Taxes. In December 2019, the FASB issued ASU 2019-12, Income Taxes (Topic 740) – Simplifying the Accounting for Income Taxes (“ASU 2019-12”). The objective of ASU 2019-12 is to simplify the accounting for income taxes by removing certain exceptions to the general principles in Topic 740 and to provide more consistent application to improve the comparability of financial statements. The amendments in this ASU are effective for fiscal years beginning after December 15, 2020, and early adoption is permitted. We are currently evaluating the impact this guidance may have on our consolidated financial statements and related footnote disclosures.

v3.20.1

Revenue Recognition (Disaggregation of Revenue) (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2020	Mar. 31, 2019
Disaggregation of Revenue [Line Items]
Revenues	$ 241,373	$ 303,362
Oil sales
Disaggregation of Revenue [Line Items]
Revenues	228,577	291,965
Natural gas sales
Disaggregation of Revenue [Line Items]
Revenues	1,047	2,612
CO2 sales and transportation fees
Disaggregation of Revenue [Line Items]
Revenues	8,028	8,570
Purchased oil sales
Disaggregation of Revenue [Line Items]
Revenues	$ 3,721	$ 215

v3.20.1

Basis of Presentation (Reconciliation of Net Income (Loss) and Weighted Average Shares Table) (Details) - USD ($) shares in Thousands, $ in Thousands		3 Months Ended
		Mar. 31, 2020	Mar. 31, 2019
Numerator
Net income (loss) - basic		$ 74,016	$ (25,674)
Interest on convertible senior notes including amortization of discount, net of tax		5,857	0
Net income (loss) - diluted		$ 79,873	$ (25,674)
Denominator
Weighted average common shares outstanding - basic		494,259	451,720
Restricted stock and performance-based equity awards		1,078	0
Convertible senior notes	[1]	90,853	0
Weighted average common shares outstanding - diluted		586,190	451,720
Debt Instrument, Convertible, Number of Equity Instruments		90,900
[1] For the three months ended March 31, 2020, shares shown under “convertible senior notes” represent the impact over the period of the approximately 90.9 million shares of the Company’s common stock issuable upon full conversion of our convertible senior notes which were issued on June 19, 2019.

v3.20.1

Condensed Consolidated Statements of Operations (Unaudited) - USD ($) shares in Thousands, $ in Thousands	3 Months Ended
	Mar. 31, 2020	Mar. 31, 2019
Revenues and other income	$ 242,201	$ 305,452
Expenses
Taxes other than income	19,686	23,785
General and administrative expenses	9,733	18,925
Interest, net of amounts capitalized of $9,452 and $10,534, respectively	19,946	17,398
Depletion, depreciation, and amortization	96,862	57,297
Commodity derivatives expense (income)	(146,771)	83,377
Gain on debt extinguishment	(18,994)	0
Write-down of oil and natural gas properties	72,541	0
Other expenses	2,494	4,138
Total expenses	178,801	341,885
Income (loss) before income taxes	63,400	(36,433)
Income tax benefit	(10,616)	(10,759)
Net income (loss)	$ 74,016	$ (25,674)
Net income (loss) per common share
Basic	$ 0.15	$ (0.06)
Diluted	$ 0.14	$ (0.06)
Weighted average common shares outstanding
Basic	494,259	451,720
Diluted	586,190	451,720
Other income
Revenues and other income	$ 828	$ 2,090
Transportation and marketing
Operating expenses	9,621	10,773
Oil, natural gas, and related product sales
Revenues and other income	229,624	294,577
Operating expenses	109,270	125,423
CO2
Revenues and other income	8,028	8,570
Operating expenses	752	556
Purchased oil sales
Revenues and other income	3,721	215
Operating expenses	$ 3,661	$ 213

v3.20.1

Commodity Derivative Contracts (Tables)	3 Months Ended
	Mar. 31, 2020
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 March 31, 2020, 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:                               2020 Fixed-Price Swaps                               Apr – Dec   NYMEX   13,500   $ 36.25 – 61.00   $ 40.52   $ —   $ —   $ — Apr – Dec   Argus LLS   7,500     35.00 – 64.26   51.67   —   —   — 2020 Three-Way Collars(2)                               Apr – June   NYMEX   11,500   $ 55.00 – 82.65   $ —   $ 47.95   $ 57.18   $ 63.44 Apr – June   Argus LLS   7,000     58.00 – 87.10   —   52.93   62.09   69.54 July – Dec   NYMEX   9,500     55.00 – 82.65   —   47.93   57.00   63.25 July – Dec   Argus LLS   5,000     58.00 – 87.10   —   52.80   61.63   70.35 (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 oil prices average less than the sold put price, our receipts on settlement would be limited to the difference between the floor price and the sold put price for the contracted volumes.

v3.20.1

Additional Balance Sheet Details (Trade and Other Receivables, Net) (Details) - USD ($) $ in Thousands	Mar. 31, 2020	Dec. 31, 2019
Receivables [Abstract]
Commodity derivative settlement receivables	$ 15,396	$ 675
Trade accounts receivable, net	13,504	12,630
Federal income tax receivable, net	11,054	2,987
Other receivables	1,543	2,026
Total	$ 41,497	$ 18,318

v3.20.1

Condensed Consolidated Statements of Operations (Unaudited) (Parenthetical) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2020	Mar. 31, 2019
Expenses
Capitalized interest	$ 9,452	$ 10,534

v3.20.1

Basis of Presentation (Cash, Cash Equivalents, and Restricted Cash) (Details) - USD ($) $ in Thousands	Mar. 31, 2020	Dec. 31, 2019	Mar. 31, 2019	Dec. 31, 2018
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents [Abstract]
Cash and cash equivalents	$ 6,917	$ 516
Restricted cash included in other assets	32,657	32,529
Total cash, cash equivalents, and restricted cash shown in the Unaudited Condensed Consolidated Statements of Cash Flows	$ 39,574	$ 33,045	$ 22,307	$ 54,949

v3.20.1

Long-Term Debt (Tables)	3 Months Ended
	Mar. 31, 2020
Debt Disclosure [Abstract]
Components of Long-Term Debt	The table below reflects long-term debt outstanding as of the dates indicated:     March 31,   December 31, In thousands   2020   2019 Senior Secured Bank Credit Agreement   $ —   $ — 9% Senior Secured Second Lien Notes due 2021   584,709   614,919 9¼% Senior Secured Second Lien Notes due 2022   455,668   455,668 7¾% Senior Secured Second Lien Notes due 2024   531,821   531,821 7½% Senior Secured Second Lien Notes due 2024   20,641   20,641 6⅜% Convertible Senior Notes due 2024   245,548   245,548 6⅜% Senior Subordinated Notes due 2021   51,304   51,304 5½% Senior Subordinated Notes due 2022   58,426   58,426 4⅝% Senior Subordinated Notes due 2023   135,960   135,960 Pipeline financings   163,748   167,439 Total debt principal balance   2,247,825   2,281,726 Debt discount(1)   (97,873 )   (101,767 ) Future interest payable(2)   143,749   164,914 Debt issuance costs   (9,505 )   (10,009 ) Total debt, net of debt issuance costs and discount   2,284,196   2,334,864 Less: current maturities of long-term debt(3)   (98,212 )   (102,294 ) Long-term debt   $ 2,185,984   $ 2,232,570 (1) Consists of discounts related to our 7¾% Senior Secured Second Lien Notes due 2024 and 6⅜% Convertible Senior Notes due 2024 of $25.7 million and $72.2 million, respectively, as of March 31, 2020. (2) Future interest payable represents most of the interest due over the terms of our 2021 Senior Secured Notes and 9¼% Senior Secured Second Lien Notes due 2022 (the “2022 Senior Secured Notes”) and has been accounted for as debt in accordance with FASC 470-60, Troubled Debt Restructuring by Debtors. (3) Our current maturities of long-term debt as of March 31, 2020 include $83.8 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.

v3.20.1

Document and Entity Information - shares	3 Months Ended
	Mar. 31, 2020	Apr. 30, 2020
Document And Company Information [Abstract]
Document Type	10-Q
Document Quarterly Report	true
Document Period End Date	Mar. 31, 2020
Document Transition Report	false
Entity File Number	001-12935
Entity Registrant Name	DENBURY RESOURCES INC.
Entity Incorporation, State or Country Code	DE
Entity Tax Identification Number	20-0467835
Entity Address, Address Line One	5320 Legacy Drive,
Entity Address, City or Town	Plano,
Entity Address, State or Province	TX
Entity Address, Postal Zip Code	75024
City Area Code	(972)
Local Phone Number	673-2000
Title of 12(b) Security	Common Stock $.001 Par Value
Trading Symbol	DNR
Security Exchange Name	NYSE
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Large Accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Shell Company	false
Entity Common Stock, Shares Outstanding		506,481,777
Entity Central Index Key	0000945764
Current Fiscal Year End Date	--12-31
Document Fiscal Year Focus	2020
Document Fiscal Period Focus	Q1
Amendment Flag	false

v3.20.1

Divestiture (Details Textuals) - USD ($)		3 Months Ended
	Mar. 04, 2020	Mar. 31, 2020	Mar. 31, 2019
Business Combinations [Abstract]
Net proceeds from sale of oil and natural gas properties	$ 40,000,000	$ 40,543,000	$ 104,000
Gain (loss) on disposition of oil and gas properties	$ 0

v3.20.1

Divestiture	3 Months Ended
	Mar. 31, 2020
Business Combinations [Abstract]
Divestiture	Note 2. Divestiture On March 4, 2020, we closed a farm-down transaction for the sale of half of our working interest positions in four southeast Texas oil fields for $40 million net cash and a carried interest in ten wells to be drilled by the purchaser. The sale had an effective date of January 1, 2019.  We did not record a gain or loss on the sale of the properties in accordance with the full cost method of accounting.

v3.20.1

Additional Balance Sheet Details (Accounts Payable and Accrued Liabilities) (Details) - USD ($) $ in Thousands	Mar. 31, 2020	Dec. 31, 2019
Accounts Payable and Accrued Liabilities [Abstract]
Accounts payable	$ 26,134	$ 29,077
Accrued lease operating expenses	21,141	26,686
Accrued interest	16,176	25,253
Taxes payable	10,461	21,274
Accrued compensation	7,187	36,366
Accrued exploration and development costs	4,671	7,811
Other	20,776	37,365
Total	$ 106,546	$ 183,832

v3.20.1

Additional Balance Sheet Details	3 Months Ended
	Mar. 31, 2020
Disclosure Text Block [Abstract]
Additional Balance Sheet Details	Note 9. Additional Balance Sheet Details Trade and Other Receivables, Net     March 31,   December 31, In thousands   2020   2019 Commodity derivative settlement receivables   $ 15,396   $ 675 Trade accounts receivable, net   13,504   12,630 Federal income tax receivable, net   11,054   2,987 Other receivables   1,543   2,026 Total   $ 41,497   $ 18,318 Accounts Payable and Accrued Liabilities     March 31,   December 31, In thousands   2020   2019 Accounts payable   $ 26,134   $ 29,077 Accrued lease operating expenses   21,141   26,686 Accrued interest   16,176   25,253 Taxes payable   10,461   21,274 Accrued compensation   7,187   36,366 Accrued exploration and development costs   4,671   7,811 Other   20,776   37,365 Total   $ 106,546   $ 183,832

v3.20.1

Income Taxes	3 Months Ended
	Mar. 31, 2020
Income Tax Disclosure [Abstract]
Income Taxes	Note 5. Income Taxes On March 27, 2020, Congress enacted the Coronavirus Aid, Relief, and Economic Security Act (the “CARES Act”) to provide certain taxpayer relief as a result of the COVID-19 pandemic. The CARES Act included several favorable provisions that impacted income taxes, primarily the modified rules on the deductibility of business interest expense for 2019 and 2020, a five-year carryback period for net operating losses generated after 2017 and before 2021, and the acceleration of refundable alternative minimum tax credits. We evaluate our estimated annual effective income tax rate based on current and forecasted business results and enacted tax laws on a quarterly basis and apply this tax rate to our ordinary income or loss to calculate our estimated tax liability or benefit. Our income taxes are based on an estimated statutory rate of approximately 25% in 2020 and 2019. Our effective tax rate for the three months ended March 31, 2020, differed from our estimated statutory rate, primarily due to tax changes enacted by the CARES Act which resulted in the full release of a $24.5 million valuation allowance against a portion of our business interest expense deduction that we previously estimated would be disallowed, offset by the establishment of a valuation allowance on a portion of our enhanced oil recovery credits that currently are not expected to be utilized.

v3.20.1

Commitments and Contingencies (Loss Contingencies) (Details) $ in Millions	Mar. 31, 2020 USD ($)
Loss Contingencies [Line Items]
Estimated litigation liability	$ 51.7
Amount of letter of credit posted as security	32.8
Total liquidated damages
Loss Contingencies [Line Items]
Estimated litigation liability	46.0
Other costs associated with the settlement
Loss Contingencies [Line Items]
Estimated litigation liability	$ 5.7

v3.20.1

Long-Term Debt (Components of Long-Term Debt) (Details) - USD ($) $ in Thousands		Mar. 31, 2020	Dec. 31, 2019
Debt Instrument [Line Items]
Senior Secured Bank Credit Agreement		$ 0	$ 0
Pipeline financings		163,748	167,439
Total debt principal balance		2,247,825	2,281,726
Debt discount	[1]	(97,873)	(101,767)
Future interest payable	[2]	143,749	164,914
Debt issuance costs		(9,505)	(10,009)
Total debt, net of debt issuance costs and discount		2,284,196	2,334,864
Less: current maturities of long-term debt	[3]	(98,212)	(102,294)
Long-term debt		2,185,984	2,232,570
9% Senior Secured Second Lien Notes due 2021
Debt Instrument [Line Items]
Long-term Debt, Gross		$ 584,709	614,919
Stated interest rate percentage		9.00%
9 1/4% Senior Secured Second Lien Notes due 2022
Debt Instrument [Line Items]
Long-term Debt, Gross		$ 455,668	455,668
Stated interest rate percentage		9.25%
7 3/4% Senior Secured Second Lien Notes due 2024
Debt Instrument [Line Items]
Long-term Debt, Gross		$ 531,821	531,821
Debt discount		$ (25,700)
Stated interest rate percentage		7.75%
7 1/2% Senior Secured Second Lien Notes due 2024
Debt Instrument [Line Items]
Long-term Debt, Gross		$ 20,641	20,641
Stated interest rate percentage		7.50%
6 3/8% Convertible Senior Notes due 2024
Debt Instrument [Line Items]
Long-term Debt, Gross		$ 245,548	245,548
Debt discount		$ (72,200)
Stated interest rate percentage		6.375%
6 3/8% Senior Subordinated Notes due 2021
Debt Instrument [Line Items]
Long-term Debt, Gross		$ 51,304	51,304
Stated interest rate percentage		6.375%
5 1/2% Senior Subordinated Notes due 2022
Debt Instrument [Line Items]
Long-term Debt, Gross		$ 58,426	58,426
Stated interest rate percentage		5.50%
4 5/8% Senior Subordinated Notes due 2023
Debt Instrument [Line Items]
Long-term Debt, Gross		$ 135,960	135,960
Stated interest rate percentage		4.625%
Future interest payable on senior secured notes
Debt Instrument [Line Items]
Less: current maturities of long-term debt		$ (83,751)	(86,054)
Long-term debt		$ 59,998	$ 78,860
[1] Consists of discounts related to our 7¾% Senior Secured Second Lien Notes due 2024 and 6⅜% Convertible Senior Notes due 2024 of $25.7 million and $72.2 million, respectively, as of March 31, 2020 [2] Future interest payable represents most of the interest due over the terms of our 2021 Senior Secured Notes and 9¼% Senior Secured Second Lien Notes due 2022 (the “2022 Senior Secured Notes”) and has been accounted for as debt in accordance with FASC 470-60, Troubled Debt Restructuring by Debtors. [3] Our current maturities of long-term debt as of March 31, 2020 include $83.8 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.

v3.20.1

Fair Value Measurements (Fair Value Hierarchy Table) (Details) - USD ($) $ in Thousands	Mar. 31, 2020	Dec. 31, 2019
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Oil derivative contracts - current assets	$ 125,724	$ 11,936
Total Assets	125,724	11,936
Oil derivative contracts - current liabilities	0	(8,346)
Total Liabilities		(8,346)
Quoted Prices in Active Markets (Level 1)
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Oil derivative contracts - current assets	0	0
Total Assets	0	0
Oil derivative contracts - current liabilities		0
Total Liabilities		0
Significant Other Observable Inputs (Level 2)
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Oil derivative contracts - current assets	125,724	8,503
Total Assets	125,724	8,503
Oil derivative contracts - current liabilities		(6,522)
Total Liabilities		(6,522)
Significant Unobservable Inputs (Level 3)
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Oil derivative contracts - current assets	0	3,433
Total Assets	$ 0	3,433
Oil derivative contracts - current liabilities		(1,824)
Total Liabilities		$ (1,824)

v3.20.1

Condensed Consolidated Statement of Changes in Stockholders' Equity (Unaudited) - 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, 2018		462,355,725			1,941,749
Beginning balance at Dec. 31, 2018	$ 1,141,777	$ 462	$ 2,685,211	$ (1,533,112)	$ (10,784)
Issued or purchased pursuant to stock compensation plans, shares		1,331,050
Issued or purchased pursuant to stock compensation plans, value	2	$ 2
Issued pursuant to directors' compensation plan, shares		41,487
Stock-based compensation, value	4,306		4,306
Tax withholding - stock compensation, shares					531,494
Tax withholding - stock compensation, value	(1,091)				$ (1,091)
Net income (loss)	(25,674)			(25,674)
Ending balance, shares at Mar. 31, 2019		463,728,262			2,473,243
Ending balance at Mar. 31, 2019	$ 1,119,320	$ 464	2,689,517	(1,558,786)	$ (11,875)
Beginning balance, shares at Dec. 31, 2019	508,065,495	508,065,495			1,652,771
Beginning balance at Dec. 31, 2019	$ 1,412,259	$ 508	2,739,099	(1,321,314)	$ (6,034)
Issued or purchased pursuant to stock compensation plans, shares		312,516
Issued pursuant to directors' compensation plan, shares		37,367
Stock-based compensation, value	3,204		3,204
Tax withholding - stock compensation, shares					175,673
Tax withholding - stock compensation, value	(34)				$ (34)
Net income (loss)	$ 74,016			74,016
Ending balance, shares at Mar. 31, 2020	508,415,378	508,415,378			1,828,444
Ending balance at Mar. 31, 2020	$ 1,489,445	$ 508	$ 2,742,303	$ (1,247,298)	$ (6,068)

v3.20.1

Basis of Presentation (Antidilutive Securities) (Details) - shares shares in Thousands	3 Months Ended
	Mar. 31, 2020	Mar. 31, 2019
Stock appreciation rights
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Antidilutive Securities Excluded from Computation of Earnings Per Share, Amount	1,528	2,091
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	14,007	8,350

v3.20.1

Fair Value Measurements (Tables)	3 Months Ended
	Mar. 31, 2020
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 March 31, 2020                 Assets                 Oil derivative contracts – current   $ —   $ 125,724   $ —   $ 125,724 Total Assets   $ —   $ 125,724   $ —   $ 125,724                   December 31, 2019                 Assets                 Oil derivative contracts – current   $ —   $ 8,503   $ 3,433   $ 11,936 Total Assets   $ —   $ 8,503   $ 3,433   $ 11,936                   Liabilities                 Oil derivative contracts – current   $ —   $ (6,522 )   $ (1,824 )   $ (8,346 ) Total Liabilities   $ —   $ (6,522 )   $ (1,824 )   $ (8,346 )
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 months ended March 31, 2020 and 2019:     Three Months Ended     March 31, In thousands   2020   2019 Fair value of Level 3 instruments, beginning of period   $ 1,609   $ 13,624 Transfers out of Level 3   (1,609 )   — Fair value losses on commodity derivatives   —   (9,047 ) Receipts on settlements of commodity derivatives   —   (891 ) Fair value of Level 3 instruments, end of period   $ —   $ 3,686           The amount of total losses for the period included in earnings attributable to the change in unrealized losses relating to assets or liabilities still held at the reporting date   $ —   $ (6,481 )

v3.20.1

Condensed Consolidated Balance Sheets (Unaudited) (Parenthetical) - USD ($) $ in Thousands		Mar. 31, 2020	Dec. 31, 2019
Debt Instrument [Line Items]
Future interest payable - current	[1]	$ 98,212	$ 102,294
Future interest payable - long-term		$ 2,185,984	$ 2,232,570
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		750,000,000
Common stock, shares issued		508,415,378	508,065,495
Treasury stock, shares		1,828,444	1,652,771
Future interest payable on senior secured notes
Debt Instrument [Line Items]
Future interest payable - current		$ 83,751	$ 86,054
Future interest payable - long-term		$ 59,998	$ 78,860
[1] Our current maturities of long-term debt as of March 31, 2020 include $83.8 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.

v3.20.1

Income Taxes (Details Textuals) - USD ($) $ in Millions	3 Months Ended	12 Months Ended
	Mar. 31, 2020	Dec. 31, 2019
Income Tax Disclosure [Abstract]
Statutory tax rate	25.00%	25.00%
Decrease in valuation allowance	$ (24.5)

v3.20.1

Fair Value Measurements (Details Textuals) - USD ($) $ in Millions	Mar. 31, 2020	Dec. 31, 2019
Fair Value Disclosures [Abstract]
Fair value of debt	$ 490.4	$ 1,833.1

v3.20.1

Basis of Presentation (Tables)	3 Months Ended
	Mar. 31, 2020
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   March 31, 2020   December 31, 2019 Cash and cash equivalents   $ 6,917   $ 516 Restricted cash included in other assets   32,657   32,529 Total cash, cash equivalents, and restricted cash shown in the Unaudited Condensed Consolidated Statements of Cash Flows   $ 39,574   $ 33,045
Schedule of earnings per share, basic and diluted reconciliation	The following table sets forth the reconciliations of net income (loss) and weighted average shares used for purposes of calculating the basic and diluted net income (loss) per common share for the periods indicated:     Three Months Ended     March 31, In thousands   2020   2019 Numerator         Net income (loss) – basic   $ 74,016   $ (25,674 ) Effect of potentially dilutive securities         Interest on convertible senior notes including amortization of discount, net of tax   5,857   — Net income (loss) – diluted   $ 79,873   $ (25,674 )           Denominator         Weighted average common shares outstanding – basic   494,259   451,720 Effect of potentially dilutive securities         Restricted stock and performance-based equity awards   1,078   — Convertible senior notes(1)   90,853   — Weighted average common shares outstanding – diluted   586,190   451,720 (1) For the three months ended March 31, 2020, shares shown under “convertible senior notes” represent the impact over the period of the approximately 90.9 million shares of the Company’s common stock issuable upon full conversion of our convertible senior notes which were issued on June 19, 2019.
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 (loss) per share, as their effect would have been antidilutive:     Three Months Ended     March 31, In thousands   2020   2019 Stock appreciation rights   1,528   2,091 Restricted stock and performance-based equity awards   14,007   8,350

v3.20.1

Fair Value Measurements	3 Months Ended
	Mar. 31, 2020
Fair Value Disclosures [Abstract]
Fair Value Measurements	Note 7. 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 and 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 December 31, 2019, instruments in this category included non-exchange-traded three-way collars that were based on regional pricing other than NYMEX (e.g., Light Louisiana Sweet). The valuation models utilized for three-way collars were consistent with the methodologies described above; however, the implied volatilities utilized in the valuation of Level 3 instruments were developed using a benchmark, which was considered a significant unobservable input. 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 March 31, 2020                 Assets                 Oil derivative contracts – current   $ —   $ 125,724   $ —   $ 125,724 Total Assets   $ —   $ 125,724   $ —   $ 125,724                   December 31, 2019                 Assets                 Oil derivative contracts – current   $ —   $ 8,503   $ 3,433   $ 11,936 Total Assets   $ —   $ 8,503   $ 3,433   $ 11,936                   Liabilities                 Oil derivative contracts – current   $ —   $ (6,522 )   $ (1,824 )   $ (8,346 ) Total Liabilities   $ —   $ (6,522 )   $ (1,824 )   $ (8,346 ) 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 months ended March 31, 2020 and 2019:     Three Months Ended     March 31, In thousands   2020   2019 Fair value of Level 3 instruments, beginning of period   $ 1,609   $ 13,624 Transfers out of Level 3   (1,609 )   — Fair value losses on commodity derivatives   —   (9,047 ) Receipts on settlements of commodity derivatives   —   (891 ) Fair value of Level 3 instruments, end of period   $ —   $ 3,686           The amount of total losses for the period included in earnings attributable to the change in unrealized losses relating to assets or liabilities still held at the reporting date   $ —   $ (6,481 ) Instruments previously categorized as Level 3 included non-exchange-traded three-way collars that were based on regional pricing other than NYMEX, whereby the implied volatilities utilized were developed using a benchmark, which was considered a significant unobservable input. The transfers between Level 3 and Level 2 during the period generally relate to changes in the significant relevant observable and unobservable inputs that are available for the fair value measurements of such financial instruments. 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 March 31, 2020 and December 31, 2019, excluding pipeline financing obligations, was $490.4 million and $1,833.1 million, respectively, which decrease is primarily driven by a decrease in quoted market prices. We have other financial instruments consisting primarily of cash, cash equivalents, U.S. Treasury notes, short-term receivables and payables that approximate fair value due to the nature of the instrument and the relatively short maturities.

v3.20.1

Revenue Recognition	3 Months Ended
	Mar. 31, 2020
Revenue from Contract with Customer [Abstract]
Revenue Recognition	Note 3. Revenue Recognition We record revenue in accordance with Financial Accounting Standards Board Codification (“FASC”) Topic 606, Revenue from Contracts with Customers. 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. 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 $72.5 million and $139.4 million as of March 31, 2020 and December 31, 2019, respectively. The Company enters into purchase transactions with third parties and separate sale transactions with third parties in the Gulf Coast region. Revenues and expenses from these transactions are presented on a gross basis, as we act as a principal in the transaction by assuming control of the commodities purchased and the responsibility to deliver the commodities sold. Revenue is recognized when control transfers to the purchaser at the delivery point based on the price received from the purchaser. Disaggregation of Revenue The following table summarizes our revenues by product type for the three months ended March 31, 2020 and 2019:     Three Months Ended     March 31, In thousands   2020   2019 Oil sales   $ 228,577   $ 291,965 Natural gas sales   1,047   2,612 CO2 sales and transportation fees   8,028   8,570 Purchased oil sales   3,721   215 Total revenues   $ 241,373   $ 303,362

v3.20.1

Long-Term Debt (Details Textuals)	1 Months Ended	3 Months Ended
	Mar. 31, 2020 USD ($)	Mar. 31, 2020 USD ($)	Mar. 31, 2019 USD ($)	May 13, 2020 USD ($)
Senior Secured Bank Credit Facility [Abstract]
Interest in guarantor subsidiaries	100.00%	100.00%
Credit facility, unused capacity - commitment fee percentage		0.50%
Senior secured debt to consolidated EBITDAX		2.5
Consolidated EBITDAX to consolidated interest charges		1.25
Current ratio requirement		1.0
Debt repurchases, face amount	$ 30,200,000	$ 30,200,000
Cash paid for debt repurchases	14,200,000	14,171,000	$ 0
Gain on debt extinguishment	$ 19,000,000.0	$ 18,994,000	$ 0
Subsequent Event
Senior Secured Bank Credit Facility [Abstract]
Borrowing base				$ 615,000,000
Lender commitments				$ 615,000,000
Year 2020
Senior Secured Bank Credit Facility [Abstract]
Total Debt to Consolidated EBITDAX		5.25
Q1 | Year 2021
Senior Secured Bank Credit Facility [Abstract]
Total Debt to Consolidated EBITDAX		4.50
Q2 | Year 2021
Senior Secured Bank Credit Facility [Abstract]
Total Debt to Consolidated EBITDAX		4.5
Q3 | Year 2021
Senior Secured Bank Credit Facility [Abstract]
Total Debt to Consolidated EBITDAX		4.5

v3.20.1

Fair Value Measurements (Level 3 Fair Value Measurements) (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2020	Mar. 31, 2019
Fair Value, Net Derivative Asset Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Fair value of Level 3 instruments, beginning of period	$ 1,609	$ 13,624
Transfers out of Level 3	(1,609)	0
Fair value losses on commodity derivatives	0	(9,047)
Receipts on settlements of commodity derivatives	0	(891)
Fair value of Level 3 instruments, end of period	0	3,686
The amount of total losses for the period included in earnings attributable to the change in unrealized losses relating to assets or liabilities still held at the reporting date	$ 0	$ (6,481)

v3.20.1

Commitments and Contingencies	3 Months Ended
	Mar. 31, 2020
Commitments and Contingencies Disclosure [Abstract]
Commitments and Contingencies	Note 8. 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.  We 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 (“APMTG”). The helium supply contract provides for the delivery of a minimum contracted quantity of helium, with liquidated damages payable if specified quantities of helium are not supplied in accordance with the terms of the contract. The liquidated damages 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 due to significant technical issues, we have not been able to supply helium under the helium supply contract. In a case filed in November 2014 in the Ninth Judicial District Court of Sublette County, Wyoming, APMTG claimed multiple years of liquidated damages for non-delivery of volumes of helium specified under the helium supply contract. The Company claimed that its contractual obligations were excused by virtue of events that fall within the force majeure provisions in the helium supply contract. On March 11, 2019, the trial court entered a final judgment that a force majeure condition did exist, but the Company’s performance was excused by the force majeure provisions of the contract for only a 35-day period in 2014, and as a result the Company should pay APMTG liquidated damages and interest thereon for those time periods from contract commencement to the close of evidence (November 29, 2017). The Company’s position continues to be that its contractual obligations have been and continue to be excused by events that fall within the force majeure provisions of the helium supply contract, so the Company has appealed the trial court’s ruling to the Wyoming Supreme Court. Briefing for the appeal by the Company and APMTG is currently expected to be completed in late May or early June, after which oral arguments are anticipated to be scheduled and heard prior to the Wyoming Supreme Court entering its judgment on the appeal. The timing and outcome of this appeal process is currently unpredictable, but at this time is anticipated to extend over the next six to nine months. Absent reversal of the trial court’s ruling on appeal, the Company anticipates total liquidated damages would equal the $46.0 million aggregate cap under the helium supply contract plus $5.7 million of associated costs (through March 31, 2020), for a total of $51.7 million, included in “Other liabilities” in our Unaudited Condensed Consolidated Balance Sheets as of March 31, 2020. The Company has a $32.8 million letter of credit posted as security in this case as part of the appeal process.

v3.20.1

Long-Term Debt	3 Months Ended
	Mar. 31, 2020
Debt Disclosure [Abstract]
Long-Term Debt	Note 4. Long-Term Debt The table below reflects long-term debt outstanding as of the dates indicated:     March 31,   December 31, In thousands   2020   2019 Senior Secured Bank Credit Agreement   $ —   $ — 9% Senior Secured Second Lien Notes due 2021   584,709   614,919 9¼% Senior Secured Second Lien Notes due 2022   455,668   455,668 7¾% Senior Secured Second Lien Notes due 2024   531,821   531,821 7½% Senior Secured Second Lien Notes due 2024   20,641   20,641 6⅜% Convertible Senior Notes due 2024   245,548   245,548 6⅜% Senior Subordinated Notes due 2021   51,304   51,304 5½% Senior Subordinated Notes due 2022   58,426   58,426 4⅝% Senior Subordinated Notes due 2023   135,960   135,960 Pipeline financings   163,748   167,439 Total debt principal balance   2,247,825   2,281,726 Debt discount(1)   (97,873 )   (101,767 ) Future interest payable(2)   143,749   164,914 Debt issuance costs   (9,505 )   (10,009 ) Total debt, net of debt issuance costs and discount   2,284,196   2,334,864 Less: current maturities of long-term debt(3)   (98,212 )   (102,294 ) Long-term debt   $ 2,185,984   $ 2,232,570 (1) Consists of discounts related to our 7¾% Senior Secured Second Lien Notes due 2024 and 6⅜% Convertible Senior Notes due 2024 of $25.7 million and $72.2 million, respectively, as of March 31, 2020. (2) Future interest payable represents most of the interest due over the terms of our 2021 Senior Secured Notes and 9¼% Senior Secured Second Lien Notes due 2022 (the “2022 Senior Secured Notes”) and has been accounted for as debt in accordance with FASC 470-60, Troubled Debt Restructuring by Debtors. (3) Our current maturities of long-term debt as of March 31, 2020 include $83.8 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. The ultimate parent company in our corporate structure, Denbury Resources Inc. (“DRI”), is the sole issuer of all our outstanding senior secured, convertible senior, 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”), which has been amended periodically since that time. The Bank Credit Agreement is a senior secured revolving credit facility with a maturity date of December 9, 2021, provided that the maturity date may be accelerated to earlier dates in 2021 (February 12, 2021, May 14, 2021 or August 13, 2021) if certain defined liquidity ratios are not met, or if the 2021 Senior Secured Notes due in May 2021 or 2021 Senior Subordinated Notes due in August 2021 are not repaid or refinanced by each of their respective maturity dates. The borrowing base under the Bank Credit Agreement is evaluated semi-annually, generally around May 1 and November 1. As of May 13, 2020, the bank group has not yet completed the process for the spring redetermination, and therefore the borrowing base and commitment levels currently remain at $615 million. The Company currently anticipates that the bank group will complete the redetermination process over the next several weeks, and it is currently uncertain if there will be any change to the borrowing base or banks’ commitment levels. 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. The Bank Credit Agreement contains certain financial performance covenants through the maturity of the facility, including the following: • A Consolidated Total Debt to Consolidated EBITDAX covenant, with such ratio not to exceed 5.25 to 1.0 through December 31, 2020 and 4.50 to 1.0 thereafter; • A consolidated senior secured debt to consolidated EBITDAX covenant, with such ratio not to exceed 2.5 to 1.0. 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 (i.e., Consolidated Current Assets to Consolidated Current Liabilities) of 1.0 to 1.0. For purposes of computing the current ratio per the Bank Credit Agreement, Consolidated Current Assets exclude the current portion of derivative assets but include borrowing base availability under the senior secured bank credit facility, and Consolidated Current Liabilities exclude the current portion of derivative liabilities as well as the current portions of long-term indebtedness outstanding. As of March 31, 2020, we were in compliance with all debt covenants under the Bank Credit Agreement. However, declining industry conditions and reductions in our cash flows and liquidity over the past few months have made our ability to comply with the maximum permitted ratio of total net debt to consolidated EBITDAX maintenance financial covenant in our senior secured bank credit facility increasingly unlikely if these conditions continue, and we foresee the potential to be in violation of this covenant by the end of the second or third quarter of this year. The above description of our Bank Credit Agreement and defined terms are contained in the Bank Credit Agreement and the amendments thereto. 2020 Repurchases of Senior Secured Notes During March 2020, we repurchased a total of $30.2 million in aggregate principal amount of our 2021 Senior Secured Notes in open-market transactions for a total purchase price of $14.2 million, excluding accrued interest. In connection with these transactions, we recognized a $19.0 million gain on debt extinguishment, net of unamortized debt issuance costs and future interest payable written off.

v3.20.1

Revenue Recognition (Tables)	3 Months Ended
	Mar. 31, 2020
Revenue from Contract with Customer [Abstract]
Disaggregation of Revenue	The following table summarizes our revenues by product type for the three months ended March 31, 2020 and 2019:     Three Months Ended     March 31, In thousands   2020   2019 Oil sales   $ 228,577   $ 291,965 Natural gas sales   1,047   2,612 CO2 sales and transportation fees   8,028   8,570 Purchased oil sales   3,721   215 Total revenues   $ 241,373   $ 303,362

v3.20.1

Basis of Presentation (Details Textuals)		3 Months Ended		12 Months Ended
	Mar. 31, 2020 USD ($) bbl / d $ / Barrel Rate	Mar. 31, 2020 USD ($) bbl / d Rate	Mar. 31, 2019 USD ($)	Mar. 31, 2020 USD ($) bbl / d $ / MMBTU $ / Barrel Rate	May 13, 2020 USD ($)	Dec. 31, 2019 USD ($)
Oil and Gas, Average Sale Price and Production Cost Per Unit [Line Items]
Letters of credit outstanding	$ 32,800,000	$ 32,800,000		$ 32,800,000
Average price | $ / Barrel	20
Percentage reduction in capital budget | Rate	44.00%	44.00%		44.00%
Impairment of unevaluated costs		$ 244,900,000
Write-down of oil and natural gas properties		72,541,000	$ 0
Carrying value of long lived assets subject to impairment testing	$ 1,300,000,000	1,300,000,000		$ 1,300,000,000
Impairment of long-lived assets		$ 0
Restructured derivative contracts
Oil and Gas, Average Sale Price and Production Cost Per Unit [Line Items]
Volume per day | bbl / d	14,500	14,500		14,500
9% Senior Secured Second Lien Notes due 2021
Oil and Gas, Average Sale Price and Production Cost Per Unit [Line Items]
Outstanding debt principal balance	$ 584,709,000	$ 584,709,000		$ 584,709,000		$ 614,919,000
Subsequent Event
Oil and Gas, Average Sale Price and Production Cost Per Unit [Line Items]
remaining borrowings available under bank credit facility					$ 520,300,000
Borrowing base					615,000,000
Letters of credit outstanding					$ 94,700,000
Oil
Oil and Gas, Average Sale Price and Production Cost Per Unit [Line Items]
Average price | $ / Barrel				55.17
Natural gas
Oil and Gas, Average Sale Price and Production Cost Per Unit [Line Items]
Average price | $ / MMBTU				1.68

v3.20.1

Condensed Consolidated Statements of Cash Flows (Unaudited) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2020	Mar. 31, 2019
Cash flows from operating activities
Net income (loss)	$ 74,016	$ (25,674)
Adjustments to reconcile net income (loss) to cash flows from operating activities
Depletion, depreciation, and amortization	96,862	57,297
Write-down of oil and natural gas properties	72,541	0
Deferred income taxes	(4,209)	(9,478)
Stock-based compensation	2,453	3,263
Commodity derivatives expense (income)	(146,771)	83,377
Receipt on settlements of commodity derivatives	24,638	8,206
Gain on debt extinguishment	(18,994)	0
Debt issuance costs and discounts	4,926	1,263
Other, net	(673)	908
Changes in assets and liabilities, net of effects from acquisitions
Accrued production receivable	66,937	(21,591)
Trade and other receivables	(22,914)	1,024
Other current and long-term assets	2,539	(387)
Accounts payable and accrued liabilities	(72,607)	(35,966)
Oil and natural gas production payable	(15,948)	4,605
Other liabilities	(954)	(2,481)
Net cash provided by operating activities	61,842	64,366
Cash flows from investing activities
Oil and natural gas capital expenditures	(46,016)	(86,986)
Pipelines and plants capital expenditures	(6,294)	(1,682)
Net proceeds from sales of oil and gas properties and equipment	40,543	104
Other	(4,521)	(3,237)
Net cash used in investing activities	(16,288)	(91,801)
Cash flows from financing activities
Bank repayments	(161,000)	(103,000)
Bank borrowings	161,000	103,000
Interest payments treated as a reduction of debt	(18,211)	0
Cash paid in conjunction with debt repurchases	(14,171)	0
Pipeline financing and capital lease debt repayments	(3,690)	(4,108)
Other	(2,953)	(1,099)
Net cash used in financing activities	(39,025)	(5,207)
Net increase (decrease) in cash, cash equivalents, and restricted cash	6,529	(32,642)
Cash, cash equivalents, and restricted cash at beginning of period	33,045	54,949
Cash, cash equivalents, and restricted cash at end of period	$ 39,574	$ 22,307

v3.20.1

Condensed Consolidated Balance Sheets (Unaudited) - USD ($) $ in Thousands		Mar. 31, 2020	Dec. 31, 2019
Current assets
Cash and cash equivalents		$ 6,917	$ 516
Accrued production receivable		72,470	139,407
Trade and other receivables, net		41,497	18,318
Derivative assets		125,724	11,936
Other current assets		10,312	10,434
Total current assets		256,920	180,611
Oil and natural gas properties (using full cost accounting)
Proved properties		11,683,339	11,447,680
Unevaluated properties		636,656	872,910
CO2 properties		1,198,902	1,198,846
Pipelines and plants		2,335,198	2,329,078
Other property and equipment		217,066	212,334
Less accumulated depletion, depreciation, amortization and impairment		(11,854,989)	(11,688,020)
Net property and equipment		4,216,172	4,372,828
Operating lease right-of-use assets		32,886	34,099
Other assets		101,113	104,329
Total assets		4,607,091	4,691,867
Current liabilities
Accounts payable and accrued liabilities		106,546	183,832
Oil and gas production payable		46,921	62,869
Derivative liabilities		0	8,346
Current maturities of long-term debt (including future interest payable of $83,751 and $86,054, respectively - see Note 4)	[1]	98,212	102,294
Operating lease liabilities		7,044	6,901
Total current liabilities		258,723	364,242
Long-term liabilities
Long-term debt, net of current portion (including future interest payable of $59,998 and $78,860, respectively - see Note 4)		2,185,984	2,232,570
Asset retirement obligations		173,214	177,108
Deferred tax liabilities, net		406,021	410,230
Operating lease liabilities		40,112	41,932
Other liabilities		53,592	53,526
Total long-term liabilities		2,858,923	2,915,366
Commitments and contingencies (Note 8)
Stockholders' equity
Preferred stock, $.001 par value, 25,000,000 shares authorized, none issued and outstanding		0	0
Common stock, $.001 par value, 750,000,000 shares authorized; 508,415,378 and 508,065,495 shares issued, respectively		508	508
Paid-in capital in excess of par		2,742,303	2,739,099
Accumulated deficit		(1,247,298)	(1,321,314)
Treasury stock, at cost, 1,828,444 and 1,652,771 shares, respectively		(6,068)	(6,034)
Total stockholders' equity		1,489,445	1,412,259
Total liabilities and stockholders' equity		$ 4,607,091	$ 4,691,867
[1] Our current maturities of long-term debt as of March 31, 2020 include $83.8 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.

v3.20.1

Additional Balance Sheet Details (Tables)	3 Months Ended
	Mar. 31, 2020
Table Text Block [Abstract]
Trade and Other Receivables, Net	Trade and Other Receivables, Net     March 31,   December 31, In thousands   2020   2019 Commodity derivative settlement receivables   $ 15,396   $ 675 Trade accounts receivable, net   13,504   12,630 Federal income tax receivable, net   11,054   2,987 Other receivables   1,543   2,026 Total   $ 41,497   $ 18,318
Accounts Payable and Accrued Liabilities	Accounts Payable and Accrued Liabilities     March 31,   December 31, In thousands   2020   2019 Accounts payable   $ 26,134   $ 29,077 Accrued lease operating expenses   21,141   26,686 Accrued interest   16,176   25,253 Taxes payable   10,461   21,274 Accrued compensation   7,187   36,366 Accrued exploration and development costs   4,671   7,811 Other   20,776   37,365 Total   $ 106,546   $ 183,832

This regulatory filing also includes additional resources:
dnr-20200331x10q.pdf