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Denbury Reports First Quarter 2021 Results

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PLANO, Texas, May 06, 2021 (GLOBE NEWSWIRE) -- Denbury Inc. (NYSE: DEN) (“Denbury” or the “Company”) today provided results for the first quarter of 2021, including the following key outcomes:

FIRST QUARTER 2021 HIGHLIGHTS

  • Net cash provided by operating activities was $53 million; Adjusted cash flow from operations(1) (non-GAAP measure) was $81 million.

  • Development capital expenditures totaled $20 million; Free cash flow(1) (non-GAAP measure) was $59 million.

  • Net loss totaled $70 million, or $1.38 per diluted share. Adjusted net income(1) (non-GAAP measure) was $22 million, or $0.44 per diluted share(1) (non-GAAP measure) and Adjusted EBITDAX(1) (non-GAAP measure) totaled $82 million.

  • Total production averaged 47,357 BOE/d, consistent with expectations. Severe winter weather reduced volumes for the quarter by approximately 1,400 BOE/d.

  • Approved the initial phase of the CO2 enhanced oil recovery (EOR) development at Cedar Creek Anticline (CCA), including the Greencore CO2 pipeline extension from Bell Creek to CCA.

  • Successfully closed the acquisition of the Big Sand Draw and Beaver Creek EOR fields in the Wind River Basin in early March 2021.

  • Announced Nikulas Wood as Senior Vice President to lead the Denbury Carbon Solutions team, focused on expanding the Company’s leading Carbon Capture, Use and Storage (CCUS) position to drive future value.

  • Added Cindy Yeilding to the Denbury Board of Directors. Yeilding chaired the coordinating subcommittee of the 2019 National Petroleum Council study on CCUS.

EXECUTIVE COMMENT

Chris Kendall, the Company’s President and CEO, commented, “I am pleased with our first quarter performance, and we are off to a great start to the year. Although severe winter weather temporarily impacted operations, Denbury’s low-decline and low capital-intensity asset base nonetheless delivered meaningful free cash flow in the first quarter. Looking forward to the rest of the year, we are preparing to kick off construction on our CCA CO2 pipeline in the coming weeks. The CCA EOR development, which will produce low carbon-intensity blue oil through utilization of industrial-sourced CO2, provides the Company with a deep inventory of resource development opportunities and decades of free cash flow.

The Denbury Carbon Solutions team continues to progress multiple agreements that we expect will advance significant growth in Denbury’s transport and storage of captured industrial-sourced CO2. Denbury’s proven track record of partnership with industrial emitters in providing practical, reliable, and secure CO2 transportation and storage solutions is unmatched in the industry. Considering the Company’s ideally positioned infrastructure and extensive CO2 experience, CCUS represents an incredible value creation opportunity for our Company.”

OPERATING AND FINANCIAL RESULTS

Total revenues and other income in the first quarter of 2021 were $251 million, an increase of 27% from the fourth quarter 2020 and 4% from the prior-year first quarter. The quarterly increases were primarily a result of higher realized pre-hedge oil prices, despite lower production due to severe winter weather in the first quarter 2021, natural field decline, and Denbury’s significant reduction in capital spending in 2020 related to the COVID-19 impact on global oil demand.

Denbury’s oil and natural gas production averaged 47,357 BOE/d during first quarter 2021, consistent with expectations, considering the impact of severe winter weather (lowered first quarter 2021 volumes approximately 1,400 BOE/d), as well as the March 2021 acquisition of assets in the Wind River Basin (added 870 BOE/d for the first quarter 2021). Over 97 percent of the Company’s first quarter 2021 production was oil, with two-thirds of total volumes coming from tertiary CO2 fields. Blue oil production, resulting from captured industrial-sourced CO2 injection, increased to approximately 25% of total oil volumes as of the end of the first quarter.

Denbury’s first quarter 2021 average pre-hedge realized oil price was $56.28 per barrel (“Bbl”), representing a differential of $1.54 per Bbl below NYMEX WTI oil prices. The first quarter 2021 differential was on the favorable end of the Company’s expectation of between $1.50 to $2.00 per Bbl discount to WTI.

Lease operating expenses (“LOE”) in first quarter 2021 totaled $82 million, or $19.23 per BOE. LOE was lower than anticipated in the first quarter primarily due to a favorable adjustment to power costs associated with winter storm Uri, which caused significant power outages and disrupted the Company’s operations. Under certain of Denbury’s power agreements, the Company is provided compensation for reduced power usage, which resulted in a benefit of $15 million for the quarter. The net impact to Denbury from lost production and revenues due to the storm, incremental costs incurred for recovery, and the reduced power usage benefit was estimated to be a positive $6 million for the first quarter 2021.

General and administrative (“G&A”) expenses were $32 million in first quarter 2021, in line with expectations. G&A included $18 million of non-cash expense for stock-based compensation, of which $15 million is non-recurring as the performance measures underlying those awards were achieved in the first quarter.

Commodity derivatives expense was $116 million in the first quarter of 2021, a result of the strengthening of oil prices during the period. Cash payments on hedges that settled in the first quarter totaled $38 million (representing $9.28 per Bbl), with the remaining amount representing the mark-to-market change in the value of the Company’s hedging portfolio.

Adjustments to net loss for the quarter included the $77 million mark-to-market change on hedging and a $14 million full-cost ceiling test impairment. The full-cost ceiling test impairment resulted primarily from the difference in recording the book value of acquired properties at a higher oil price than the 12-month look-back oil price used in the ceiling test.

Depletion, depreciation, and amortization was $39 million during first quarter 2021, or $9.26 per BOE. The Company’s effective tax rate for the first quarter 2021 was negligible, due primarily to a valuation allowance on its federal and state deferred tax assets which offsets the tax benefit generated from the pre-tax loss.

CAPITAL EXPENDITURES

First quarter 2021 development capital expenditures, which excluded acquisitions and capitalized interest, totaled $20 million, less than eight percent of the Company’s annual capital budget. Acquisitions of oil & natural gas properties totaled nearly $11 million for the first quarter 2021, primarily representing the net purchase price of the Big Sand Draw and Beaver Creek fields in the Wind River Basin.

FINANCIAL STRENGTH AND BANK CREDIT FACILITY

The Company’s total debt balance as of the end of the first quarter 2021 was $126 million, down $12 million from the end of 2020. Denbury had $75 million of outstanding borrowings drawn on its senior secured bank credit facility at the end of the quarter. Including unrestricted cash, total liquidity at the end of the first quarter was $483 million, after consideration of outstanding letters of credit.

The borrowing base for the Company’s $575 million senior secured bank credit facility was reaffirmed with its lending group at the end of April 2021.

HEDGING UPDATE

The Company has added new oil hedges for 2022, including certain swaps and collars to secure additional cash flows at improved prices. Details of the Company’s current hedging positions are included below:

2Q - 4Q 2021

1H 2022

2H 2022

WTI NYMEX

Volumes Hedged (Bbls/d)

29,000

15,500

8,000

Fixed-Price Swaps

Swap Price(1)

$43.86

$49.01

$55.85

WTI NYMEX

Volumes Hedged (Bbls/d)

4,000

8,000

7,000

Collars

Floor - Ceiling Price(1)

$46.25 - 53.04

$49.69 - 62.16

$49.64 - 61.66

Total Volumes Hedged (Bbls/d)

33,000

23,500

15,000


(1)

Averages are volume weighted.

REAFFIRMED ANNUAL GUIDANCE

As expected, first quarter 2021 capital spending and production were low relative to annual guidance levels. The Company’s production outlook for the year remains unchanged at a range of 47,500 to 51,500 BOE/d. Considering a full quarter’s production impact from the asset acquisition and recovery from first quarter 2021 winter storms, Denbury anticipates quarterly production volumes will increase in the second quarter 2021.

Development capital expenditures for 2021 are still expected to range from $250 million to $270 million. Second quarter capital expenditures should step up meaningfully with tertiary field work at the Oyster Bayou and Tinsley fields, as well as initial spending for construction of the extension of the Greencore CO2 pipeline and EOR development at CCA. Capital levels are expected to increase throughout the year in line with planned development activities.

Additional guidance details are available in the Company’s supplemental first quarter 2021 earnings presentation, which is available in the Investor Relations section of the Company’s website www.denbury.com.

CONFERENCE CALL AND WEBCAST INFORMATION

Denbury will host a conference call and webcast to review and discuss first quarter 2021 financial and operating results and outlook today, Thursday, May 6, at 11:00 a.m. Central Time. Additionally, Denbury will post presentation materials on its website before market open today. The presentation webcast will be available, both live and for replay, on the Investor Relations page of the Company’s website at www.denbury.com. Individuals who would like to participate in the conference call should dial the following numbers shortly before the scheduled start time: 877.705.6003 or 201.493.6725 with confirmation number 13696087.

Denbury is an independent energy company with operations and assets focused on Carbon Capture, Use and Storage (CCUS) and Enhanced Oil Recovery (EOR) in the Gulf Coast and Rocky Mountain regions. For over two decades, the Company has maintained a unique strategic focus on utilizing CO2 in its EOR operations and since 2012 has also been active in CCUS through the injection of captured industrial-sourced CO2. The Company currently injects over three million tons of captured industrial-sourced CO2 annually, and its objective is to fully offset its Scope 1, 2, and 3 CO2 emissions within this decade, primarily through increasing the amount of captured industrial-sourced CO2 used in its operations. For more information about Denbury, visit www.denbury.com.

This press release, other than historical information, contains forward-looking statements that involve risks and uncertainties including estimated 2021 production and capital expenditures, and other risks and uncertainties detailed in the Company’s filings with the Securities and Exchange Commission, including Denbury’s most recent report on Form 10-K. These risks and uncertainties are incorporated by this reference as though fully set forth herein. These statements are based on financial and market, engineering, geological and operating assumptions that management believes are reasonable based on currently available information; however, management’s assumptions and the Company’s future performance are both subject to a wide range of risks, and there is no assurance that these goals and projections can or will be met. Actual results may vary materially. In addition, any forward-looking statements represent the Company’s estimates only as of today and should not be relied upon as representing its estimates as of any future date. Denbury assumes no obligation to update its forward-looking statements.

FINANCIAL AND STATISTICAL DATA TABLES AND RECONCILIATION SCHEDULES

The following tables include selected unaudited financial and operational information for the comparative three-month periods ended March 31, 2021 and 2020. References to “Successor” refer to the new Denbury reporting entity after the Company’s emergence from bankruptcy on September 18, 2020, and references to “Predecessor” refer to the Denbury entity prior to emergence from bankruptcy. All production volumes and dollars are expressed on a net revenue interest basis with gas volumes converted to equivalent barrels at 6:1.

DENBURY INC.
CONSOLIDATED STATEMENTS OF OPERATIONS (UNAUDITED)

The following information is based on GAAP reporting earnings (along with additional required disclosures) included or to be included in the Company’s periodic reports:

Successor

Predecessor

Quarter Ended

Quarter Ended

In thousands, except per-share data

March 31, 2021

March 31, 2020

Revenues and other income

Oil sales

$

233,044

$

228,577

Natural gas sales

2,401

1,047

CO2 sales and transportation fees

9,228

8,028

Oil marketing revenues

6,126

3,721

Other income

360

828

Total revenues and other income

251,159

242,201

Expenses

Lease operating expenses

81,970

109,270

Transportation and marketing expenses

7,797

9,621

CO2 operating and discovery expenses

993

752

Taxes other than income

18,963

19,686

Oil marketing expenses

6,085

3,661

General and administrative expenses

31,983

9,733

Interest, net of amounts capitalized of $1,083 and $9,452, respectively

1,536

19,946

Depletion, depreciation, and amortization

39,450

96,862

Commodity derivatives expense (income)

115,743

(146,771

)

Gain on debt extinguishment

(18,994

)

Write-down of oil and natural gas properties

14,377

72,541

Other expenses

2,146

2,494

Total expenses

321,043

178,801

Income (loss) before income taxes

(69,884

)

63,400

Income tax provision (benefit)

Current income taxes

(191

)

(6,407

)

Deferred income taxes

(51

)

(4,209

)

Net income (loss)

$

(69,642

)

$

74,016

Net income (loss) per common share

Basic

$

(1.38

)

$

0.15

Diluted

$

(1.38

)

$

0.14

Weighted average common shares outstanding

Basic

50,319

494,259

Diluted

50,319

586,190

DENBURY INC.
CONSOLIDATED STATEMENTS OF CASH FLOWS (UNAUDITED)

Successor

Predecessor

Quarter Ended

Quarter Ended

In thousands

March 31, 2021

March 31, 2020

Cash flows from operating activities

Net income (loss)

$

(69,642

)

$

74,016

Adjustments to reconcile net income (loss) to cash flows from operating activities

Depletion, depreciation, and amortization

39,450

96,862

Write-down of oil and natural gas properties

14,377

72,541

Deferred income taxes

(51

)

(4,209

)

Stock-based compensation

17,680

2,453

Commodity derivatives expense (income)

115,743

(146,771

)

Receipt (payment) on settlements of commodity derivatives

(38,453

)

24,638

Gain on debt extinguishment

(18,994

)

Debt issuance costs and discounts

685

4,926

Other, net

727

(673

)

Changes in assets and liabilities, net of effects from acquisitions

Accrued production receivable

(36,750

)

66,937

Trade and other receivables

865

(22,914

)

Other current and long-term assets

(2,542

)

2,539

Accounts payable and accrued liabilities

(1,402

)

(72,607

)

Oil and natural gas production payable

12,795

(15,948

)

Other liabilities

(826

)

(954

)

Net cash provided by operating activities

52,656

61,842

Cash flows from investing activities

Oil and natural gas capital expenditures

(19,627

)

(46,016

)

Acquisitions of oil and natural gas properties

(10,665

)

(42

)

Pipelines and plants capital expenditures

(458

)

(6,294

)

Net proceeds from sales of oil and natural gas properties and equipment

3

40,543

Other

(2,916

)

(4,479

)

Net cash used in investing activities

(33,663

)

(16,288

)

Cash flows from financing activities

Bank repayments

(202,000

)

(161,000

)

Bank borrowings

207,000

161,000

Interest payments treated as a reduction of debt

(18,211

)

Cash paid in conjunction with debt repurchases

(14,171

)

Pipeline financing debt repayments

(16,509

)

(3,690

)

Other

(3,013

)

(2,953

)

Net cash used in financing activities

(14,522

)

(39,025

)

Net increase in cash, cash equivalents, and restricted cash

4,471

6,529

Cash, cash equivalents, and restricted cash at beginning of period

42,248

33,045

Cash, cash equivalents, and restricted cash at end of period

$

46,719

$

39,574

DENBURY INC.
CONSOLIDATED BALANCE SHEETS (UNAUDITED)

Successor

In thousands, except par value and share data

March 31, 2021

Dec. 31, 2020

Assets

Current assets

Cash and cash equivalents

$

5,647

$

518

Restricted cash

400

1,000

Accrued production receivable

128,171

91,421

Trade and other receivables, net

18,322

19,682

Derivative assets

236

187

Prepaids

9,043

14,038

Total current assets

161,819

126,846

Property and equipment

Oil and natural gas properties (using full cost accounting)

Proved properties

936,742

851,208

Unevaluated properties

86,878

85,304

CO2 properties

188,516

188,288

Pipelines

133,722

133,485

Other property and equipment

92,037

86,610

Less accumulated depletion, depreciation, amortization and impairment

(89,538

)

(41,095

)

Net property and equipment

1,348,357

1,303,800

Operating lease right-of-use assets

19,832

20,342

Derivative assets

3,021

Intangible assets, net

95,096

97,362

Other assets

93,035

86,408

Total assets

$

1,721,160

$

1,634,758

Liabilities and Stockholders’ Equity

Current liabilities

Accounts payable and accrued liabilities

$

118,189

$

112,671

Oil and gas production payable

61,960

49,165

Derivative liabilities

129,124

53,865

Current maturities of long-term debt

51,499

68,008

Operating lease liabilities

2,660

1,350

Total current liabilities

363,432

285,059

Long-term liabilities

Long-term debt, net of current portion

75,000

70,000

Asset retirement obligations

223,465

179,338

Derivative liabilities

10,188

5,087

Deferred tax liabilities, net

1,224

1,274

Operating lease liabilities

18,961

19,460

Other liabilities

26,964

20,872

Total long-term liabilities

355,802

296,031

Commitments and contingencies

Stockholders’ equity

Preferred stock, $.001 par value, 50,000,000 shares authorized, none issued and outstanding

Common stock, $.001 par value, 250,000,000 shares authorized; 50,005,619 and 49,999,999 shares issued, respectively

50

50

Paid-in capital in excess of par

1,122,176

1,104,276

Accumulated deficit

(120,300

)

(50,658

)

Total stockholders equity

1,001,926

1,053,668

Total liabilities and stockholders’ equity

$

1,721,160

$

1,634,758

DENBURY INC.
OPERATING HIGHLIGHTS (UNAUDITED)

All production volumes and dollars are expressed on a net revenue interest basis with gas volumes converted to equivalent barrels at 6:1.

Quarter Ended

March 31,

2021

2020

Average daily production (BOE/d)

Tertiary

Gulf Coast region

24,281

28,931

Rocky Mountain region

7,187

7,930

Total tertiary production

31,468

36,861

Non-tertiary

Gulf Coast region

3,621

4,173

Rocky Mountain region

12,268

14,151

Total non-tertiary production

15,889

18,324

Total Company

Oil (Bbls/d)

46,007

54,649

Natural gas (Mcf/d)

8,102

7,899

BOE (6:1)

47,357

55,965

Unit sales price (excluding derivative settlements)

Gulf Coast region

Oil (per barrel)

$

56.46

$

47.52

Natural gas (per mcf)

3.39

1.81

Rocky Mountain region

Oil (per barrel)

$

56.03

$

43.57

Natural gas (per mcf)

3.20

0.96

Total Company

Oil (per barrel)(1)

$

56.28

$

45.96

Natural gas (per mcf)

3.29

1.46

BOE (6:1)

55.24

45.09


(1)

Total company realized oil prices including derivative settlements during the three months ended March 31, 2021 and 2020 were $47.00 per Bbl and $50.92 per Bbl, respectively.

DENBURY INC.
SUPPLEMENTAL NON-GAAP FINANCIAL MEASURES (UNAUDITED)

Reconciliation of net income (loss) (GAAP measure) to adjusted net income (non-GAAP measure)

Adjusted net income is a non-GAAP measure provided as a supplement to present an alternative net income (loss) measure which excludes expense and income items (and their related tax effects) not directly related to the Company’s ongoing operations. Management believes that adjusted net income may be helpful to investors by eliminating the impact of noncash and/or special or unusual items not indicative of the Company’s performance from period to period, and is widely used by the investment community, while also being used by management, in evaluating the comparability of the Company’s ongoing operational results and trends. Adjusted net income should not be considered in isolation, as a substitute for, or more meaningful than, net income (loss) or any other measure reported in accordance with GAAP, but rather to provide additional information useful in evaluating the Company’s operational trends and performance.

Successor

Predecessor

Quarter Ended

Quarter Ended

March 31, 2021

March 31, 2020

In thousands, except per-share data

Amount

Per Diluted Share

Amount

Per Diluted Share

Net income (loss) (GAAP measure)(1)

$

(69,642

)

$

(1.38

)

$

74,016

$

0.14

Adjustments to reconcile to adjusted net income (non-GAAP measure)

Noncash fair value losses (gains) on commodity derivatives(2)

77,290

1.51

(122,133

)

(0.21

)

Write-down of oil and natural gas properties(3)

14,377

0.28

72,541

0.12

Accelerated depreciation charge(4)

37,368

0.06

Gain on debt extinguishment(5)

(18,994

)

(0.03

)

Other(6)

325

0.03

1,404

0.00

Estimated income taxes on above adjustments to net income (loss) and other discrete tax items(7)

(16,782

)

(0.02

)

Adjusted net income (non-GAAP measure)

$

22,350

$

0.44

$

27,420

$

0.06


(1)

Diluted net income (loss) per common share includes the impact of potentially dilutive securities including performance stock units, nonvested restricted stock units, and warrants during the Successor period and includes nonvested restricted stock, nonvested performance-based equity awards, and shares into which the Predecessor’s previous convertible senior notes were convertible.

(2)

The net change between periods of the fair market values of open commodity derivative positions, excluding the impact of settlements on commodity derivatives during the period.

(3)

Full cost pool ceiling test write-downs related to the Company’s oil and natural gas properties.

(4)

Accelerated depreciation related to impaired unevaluated properties that were transferred to the full cost pool.

(5)

Gain on debt extinguishment related to the Company’s 2020 open market repurchases.

(6)

Other adjustments include (a) a $0.3 million write-off of trade receivables during the three months ended March 31, 2021 and (b) <$1 million of costs associated with the helium supply contract ruling and $1 million of costs associated with the Delta-Tinsley CO2 pipeline incident during the three months ended March 31, 2020.

(7)

The estimated income tax impacts on adjustments to net income for the three months ended March 31, 2020 are computed based upon an estimated annual effective tax rate of 16%, with other discrete tax adjustments totaling $39 million primarily comprised of the tax effect of the ceiling test and accelerated depreciation, impacts of the CARES Act, and the periodic tax impacts of a shortfall (benefit) on the stock-based compensation deduction.

DENBURY INC.
SUPPLEMENTAL NON-GAAP FINANCIAL MEASURES (UNAUDITED)

Reconciliation of net income (loss) (GAAP measure) to Adjusted EBITDAX (non-GAAP measure)

Adjusted EBITDAX is a non-GAAP measure which management uses and is calculated based upon (but not identical to) a financial covenant related to “Consolidated EBITDAX” in the Company’s senior secured bank credit facility, which excludes certain items that are included in net income (loss), the most directly comparable GAAP financial measure. Items excluded include interest, income taxes, depletion, depreciation, and amortization, and items that the Company believes affect the comparability of operating results such as items whose timing and/or amount cannot be reasonably estimated or are nonrecurring. Management believes Adjusted EBITDAX may be helpful to investors in order to assess the Company’s operating performance as compared to that of other companies in the industry, without regard to financing methods, capital structure or historical costs basis. It is also commonly used by third parties to assess leverage and the Company’s ability to incur and service debt and fund capital expenditures. Adjusted EBITDAX should not be considered in isolation, as a substitute for, or more meaningful than, net income (loss), cash flow from operations, or any other measure reported in accordance with GAAP. The Company’s Adjusted EBITDAX may not be comparable to similarly titled measures of another company because all companies may not calculate Adjusted EBITDAX, EBITDAX or EBITDA in the same manner. The following table presents a reconciliation of the Company’s net income (loss) to Adjusted EBITDAX.

Successor

Predecessor

In thousands

Quarter Ended

Quarter Ended

March 31, 2021

March 31, 2020

Net income (loss) (GAAP measure)

$

(69,642

)

$

74,016

Adjustments to reconcile to Adjusted EBITDAX

Interest expense

1,536

19,946

Income tax expense (benefit)

(242

)

(10,616

)

Depletion, depreciation, and amortization

39,450

96,862

Noncash fair value losses (gains) on commodity derivatives

77,290

(122,133

)

Stock-based compensation

17,680

2,453

Gain on debt extinguishment

(18,994

)

Write-down of oil and natural gas properties

14,377

72,541

Noncash, non-recurring and other

1,467

2,364

Adjusted EBITDAX (non-GAAP measure)(1)

$

81,916

$

116,439


(1)

Excludes pro forma adjustments related to qualified acquisitions or dispositions under the Company’s senior secured bank credit facility.

DENBURY INC.
SUPPLEMENTAL NON-GAAP FINANCIAL MEASURES (UNAUDITED)

Reconciliation of cash flows from operations (GAAP measure) to adjusted cash flows from operations (non-GAAP measure) and free cash flow (non-GAAP measure)

Adjusted cash flows from operations is a non-GAAP measure that represents cash flows provided by operations before changes in assets and liabilities, as summarized from the Company’s Unaudited Condensed Consolidated Statements of Cash Flows. Adjusted cash flows from operations measures the cash flows earned or incurred from operating activities without regard to the collection or payment of associated receivables or payables. Free cash flow is a non-GAAP measure that represents adjusted cash flows from operations less interest treated as debt reduction, development capital expenditures and capitalized interest, but before acquisitions. Management believes that it is important to consider these additional measures, along with cash flows from operations, as it believes the non-GAAP measures can often be a better way to discuss changes in operating trends in its business caused by changes in production, prices, operating costs and related factors, without regard to whether the earned or incurred item was collected or paid during that period. Adjusted cash flows from operations and free cash flow are not measures of financial performance under GAAP and should not be considered as alternatives to cash flows from operations, investing, or financing activities, nor as a liquidity measure or indicator of cash flows.

Successor

Predecessor

In thousands

Quarter Ended

Quarter Ended

March 31, 2021

March 31, 2020

Cash flows from operations (GAAP measure)

$

52,656

$

61,842

Net change in assets and liabilities relating to operations

27,860

42,947

Adjusted cash flows from operations (non-GAAP measure)

80,516

104,789

Interest on notes treated as debt reduction

(21,354

)

Development capital expenditures

(20,079

)

(38,785

)

Capitalized interest

(1,083

)

(9,452

)

Free cash flow (non-GAAP measure)

$

59,354

$

35,198

CAPITAL EXPENDITURE SUMMARY (UNAUDITED)(1)

Quarter Ended

March 31,

In thousands

2021

2020

Capital expenditure summary

Cedar Creek Anticline tertiary development

$

36

$

1,354

Other tertiary oil fields

4,080

13,372

Non-tertiary fields

8,342

10,954

Capitalized internal costs(2)

7,600

8,881

Oil and natural gas capital expenditures

20,058

34,561

Cedar Creek Anticline CO2 pipeline

21

4,175

Other CO2 pipelines, sources and other

49

Development capital expenditures

20,079

38,785

Acquisitions of oil and natural gas properties(3)

10,665

42

Capital expenditures, before capitalized interest

30,744

38,827

Capitalized interest

1,083

9,452

Capital expenditures, total

$

31,827

$

48,279


(1)

Capital expenditure amounts include accrued capital.

(2)

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

(3)

Primarily consists of working interest positions in the Wind River Basin enhanced oil recovery fields acquired on March 3, 2021.

CONTACT: DENBURY CONTACTS: Brad Whitmarsh, Executive Director, Investor Relations, 972.673.2020, brad.whitmarsh@denbury.com Susan James, Manager, Investor Relations, 972.673.2593, susan.james@denbury.com