Financial News
Denbury Reports Second Quarter 2022 Financial and Operational Results
Board authorizes $100 million increase in share repurchase program to $350 million
Denbury Inc. (NYSE: DEN) (“Denbury” or the “Company”) today provided its second quarter 2022 financial and operating results.
HIGHLIGHTS
- Second quarter 2022 cash flows provided by operating activities totaled $150 million, and adjusted cash flows from operations(1), excluding working capital changes, totaled $145 million.
- Generated $55 million of free cash flow(1) during the second quarter and $106 million year-to-date.
- Repurchased $100 million of the Company’s shares (3.2% of March 2022 shares outstanding) in June and July 2022 at $61.92 per share, with $29 million repurchased in the second quarter.
- Exited the second quarter with zero debt, a reduction of $35 million from the first quarter 2022.
- Delivered sales volumes of 46,561 barrels of oil equivalent per day (“BOE/d”), 97% crude oil.
- Increased injection of industrial-sourced CO2 used in the Company’s Enhanced Oil Recovery (“EOR”) operations to 1.2 million metric tons for the quarter, up 27% from the first quarter of 2022, with the increase primarily driven by the Company’s Cedar Creek Anticline (“CCA”) EOR development.
- Signed a definitive agreement for a planned CO2 storage site near Donaldsonville, Louisiana, covering approximately 18,000 acres and located less than five miles from the Company’s Green Pipeline.
(1) |
A non-GAAP measure. See accompanying schedules that reconcile GAAP to non-GAAP measures along with a statement indicating why the Company believes the non-GAAP measures provide useful information for investors. |
|
(2) |
Calculated using weighted average diluted shares outstanding of 54.9 million for both the three and six months ended June 30, 2022, respectively. |
EXECUTIVE COMMENT
Chris Kendall, the Company’s President and CEO, commented, “In the second quarter, Denbury maintained excellent safety performance, continued to advance our CCUS business, made significant progress on our capital development program, and delivered robust financial results. Strong oil prices have meaningfully increased our cash flow outlook and positioned us to return significant capital to our shareholders, while still investing for moderate production growth and rapidly growing our CCUS business. During June and July 2022, we repurchased $100 million of the Company’s outstanding shares, and I’m pleased that our Board recently increased our share repurchase authorization by the same amount.
“Despite inflation headwinds and the ongoing supply chain issues affecting our industry and businesses globally, our teams have executed well on our 2022 capital program, which we expect will drive increased production in the latter part of this year. The development of our major EOR project at Cedar Creek Anticline is progressing well, and we are excited about the expected production and cash flow benefit to our business beginning next year and for decades to come.
“On the CCUS front, we continue to expand what we believe is the industry’s superior CCUS platform, adding another planned CO2 storage site in the emissions-intensive Louisiana industrial corridor. With multiple ongoing industrial customer negotiations, we remain on track to substantially exceed our 2022 goals for CO2 offtake. Our proven track record in providing highly reliable CO2 transportation and secure underground injection, combined with our ideally-placed infrastructure, is unmatched in the industry and positions us well for continued success and growth in CCUS.”
SECOND QUARTER FINANCIAL AND OPERATIONAL RESULTS
|
|
2Q 2022 |
|
YTD 2022 |
||||
(in thousands, except per-share and volume data) |
|
Total |
|
Per Diluted Share |
|
Total |
|
Per Diluted Share |
Net Income |
|
$155,494 |
|
$2.83 |
|
$154,622 |
|
$2.81 |
Adjusted net income(1)(2) (non-GAAP) |
|
93,001 |
|
1.69 |
|
186,123 |
|
3.39 |
Adjusted EBITDAX(1) (non-GAAP) |
|
154,404 |
|
|
|
285,251 |
|
|
Cash flows from operations |
|
149,965 |
|
|
|
240,108 |
|
|
Adjusted cash flows from operations(1) (non-GAAP) |
|
145,190 |
|
|
|
275,770 |
|
|
Oil & gas development capital expenditures |
|
86,290 |
|
|
|
143,896 |
|
|
CCUS capital expenditures - storage sites and related assets |
|
2,951 |
|
|
|
23,900 |
|
|
|
|
|
|
|
|
|
|
|
Average daily sales volumes (BOE/d) |
|
46,561 |
|
|
|
46,742 |
|
|
Blue Oil (% oil volumes using industrial-sourced CO2) |
|
28% |
|
|
|
26% |
|
|
Industrial-sourced CO2 injected (thousand metric tons) |
|
1,185 |
|
|
|
2,124 |
|
|
Total revenues and other income in the second quarter of 2022 were $482 million, a 17% increase over first quarter 2022 levels, supported by higher oil price realizations. The Company’s average oil price differential in both the Rocky Mountain and Gulf Coast regions was better than expected and strengthened significantly during the second quarter based on improved local markets for the Company’s high-quality production. Denbury’s second quarter 2022 average pre-hedge realized oil price was $108.81 per barrel (“Bbl”), which was $0.09 per Bbl above the average NYMEX WTI oil price for the period.
Denbury’s oil and natural gas sales volumes averaged 46,561 BOE/d during the second quarter of 2022, in line with expectations. Oil represented 97% of the Company’s second quarter 2022 volumes, and approximately 28% of the Company’s oil was attributable to the injection of industrial-sourced CO2 in its EOR operations, resulting in carbon-negative or blue oil. Second quarter sales volumes were slightly lower compared to the first quarter of 2022, as the Gulf Coast volumes were impacted by compressor downtime and well repair activities, while volumes in the Rocky Mountain region increased primarily due to CO2 flood response at Grieve, development and workover activities at Beaver Creek, as well as reduced weather downtime at CCA.
Lease operating expenses (“LOE”) in the second quarter of 2022 totaled $124 million, which included a benefit of approximately $7 million as a result of a settlement of a 2013 insurance claim related to property damage at our Delhi field. Excluding this benefit, LOE per BOE was $30.93, up from the first quarter of 2022 primarily as a result of service cost inflation, higher workover activity levels, increased power and fuel costs and increased CO2 costs.
General and administrative (“G&A”) expenses were $19 million in the second quarter of 2022, slightly higher than the first quarter of 2022 due primarily to an increase in stock-based compensation.
On a pre-hedge basis, per barrel cash operating margins (revenues less LOE, production and ad valorem taxes, transportation and marketing expenses, and G&A and interest costs) expanded 22% in the quarter to $61.31 per BOE, excluding the insurance reimbursement item impacting LOE.
Commodity derivatives expense in the second quarter of 2022 totaled $57 million, comprised of cash payments of $128 million on hedges that settled in the quarter and a non-cash fair value gain of $71 million. The non-cash fair value gain primarily represented the expiration of hedge contracts during the second quarter of 2022. Depletion, depreciation, and amortization was $35 million, or $8.35 per BOE for the quarter, relatively consistent with the first quarter of the year.
The Company’s second quarter 2022 effective income tax rate was approximately 14%, consistent with expectations and lower than the Company’s 25% statutory rate due to a $19 million valuation allowance release during the second quarter of 2022. Current taxes totaled $3 million for the second quarter of 2022, or 12% of total income taxes.
CAPITAL EXPENDITURES
Second quarter 2022 capital expenditures, excluding capitalized interest, totaled $89 million, with $86 million related to oil and gas development capital and $3 million related to CCUS business activities. Capital expenditures at the CCA EOR project totaled $21 million for the second quarter of 2022, including field development and infrastructure expenditures, as well as the capitalization of pre-production CO2 injection. CO2 injection at the CCA EOR project continues to progress well, with oil production response still expected during the second half of 2023.
Non-CCA oil and gas development capital increased 74% from the first quarter of the year with focus on expansion in existing EOR assets, including Beaver Creek, Cranfield, Heidelberg and Soso field activities.
FINANCIAL POSITION, LIQUIDITY AND SHARE REPURCHASES
Denbury ended the second quarter 2022 with no debt and $738 million of financial liquidity (including cash on hand and borrowing capacity under the Company’s bank credit facility). The Company repurchased $29 million of its common stock during the second quarter and a total of $100 million, or 1.6 million shares (3.2% of March 2022 shares outstanding), through July 2022.
Denbury’s Board of Directors recently authorized a $100 million increase in the share repurchase program raising the total authorization to $350 million (which represents approximately 10% of Denbury’s current market capitalization). $250 million is available for repurchase under the plan. The timing and amount of any share repurchases will be determined by Denbury’s management at its discretion based on ongoing assessments of the capital needs of the business, the market price of Denbury’s common stock and general market conditions.
During the second quarter, the Company amended its bank credit agreement, which among other things: (i) increased the borrowing base and lender commitments from $575 million to $750 million, (ii) extended the maturity date from January 30, 2024, to May 4, 2027, and (iii) relaxed certain covenants, such as permitting the Company to implement shareholder returns and make other unlimited restricted payments and investments so long as certain leverage and availability requirements are met.
OUTLOOK
Denbury is increasing its anticipated full-year 2022 oil and gas capital expenditures to $360 million, up from the previously-guided $320 million. Approximately half of the increase is due to overall service cost inflation impacting the Company’s operations, primarily related to labor and steel costs. The remainder of the increase is associated with CCA EOR development capital, where the Company is accelerating the purchase of compression equipment and the construction of CO2 recycle facilities to mitigate timing risks associated with ongoing supply chain disruptions and to ensure the field is ready to process the expected oil production response. The Company anticipates oil and gas capital expenditures to peak in the third quarter of the year.
Capital expenditures for the CCUS business are planned at $50 million for 2022, but could increase depending on activity levels in the second half of the year. Denbury’s current plans for 2022 include drilling one or more stratigraphic test wells in the Company’s potential CO2 sequestration sites.
The Company’s full-year 2022 production guidance range is unchanged at between 46,000 and 49,000 BOE/d. For the third quarter, the Company anticipates sales volumes will be roughly flat compared to the second quarter of the year before increasing significantly in the fourth quarter, driven by incremental production from multiple projects in the Company’s 2022 capital program.
Updates to Denbury’s 2022 guidance can be found in the supporting materials on Denbury’s website.
CONFERENCE CALL AND WEBCAST
Denbury management will host a conference call and webcast to review second quarter 2022 financial and operating results and its outlook for future periods, today, Thursday, August 4, at 11:00 a.m. Central Time (12:00 p.m. Eastern Time). Additionally, Denbury will post supporting materials on its website before market open today. The 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: 844.200.6205 or 929.526.1599 with access code 048168.
ABOUT DENBURY
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 four million tons of captured industrial-sourced CO2 annually, with an objective to fully offset its Scope 1, 2, and 3 CO2 emissions by 2030, 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 and updated supporting materials, other than historical information, contains forward-looking statements that involve risks and uncertainties including: expectations as to future oil prices, operating costs, production levels and cash flows; anticipated levels of 2022 capital expenditures, lease operating expenses and general and administrative expenses, along with other financial forecasts; future tax benefits; the expected timing of first tertiary production at CCA; statements or predictions related to the ultimate economics of proposed carbon capture, use and storage arrangements and the CO2 volumes covered by such arrangements; 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 oil pricing, 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, especially in light of the Russian war against Ukraine, changes in European energy supplies, rising levels of economic uncertainty due to inflation, rising interest rates, and the continuing impact of COVID-19. 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 and six-month periods ended June 30, 2022 and 2021. All sales 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: |
||||||||||||||
|
|
Quarter Ended |
|
Six Months Ended |
||||||||||
|
|
June 30, |
|
June 30, |
||||||||||
In thousands, except per-share data |
|
2022 |
|
2021 |
|
2022 |
|
2021 |
||||||
Revenues and other income |
|
|
|
|
|
|
|
|
||||||
Oil sales |
|
$ |
446,592 |
|
$ |
280,577 |
|
|
$ |
827,834 |
|
$ |
513,621 |
|
Natural gas sales |
|
|
5,378 |
|
|
2,131 |
|
|
|
9,047 |
|
|
4,532 |
|
CO2 sales and transportation fees |
|
|
12,610 |
|
|
10,134 |
|
|
|
26,032 |
|
|
19,362 |
|
Oil marketing revenues |
|
|
16,786 |
|
|
7,819 |
|
|
|
30,062 |
|
|
13,945 |
|
Other income |
|
|
790 |
|
|
707 |
|
|
|
1,040 |
|
|
1,067 |
|
Total revenues and other income |
|
|
482,156 |
|
|
301,368 |
|
|
|
894,015 |
|
|
552,527 |
|
Expenses |
|
|
|
|
|
|
|
|
||||||
Lease operating expenses |
|
|
124,351 |
|
|
110,225 |
|
|
|
242,179 |
|
|
192,195 |
|
Transportation and marketing expenses |
|
|
4,802 |
|
|
8,522 |
|
|
|
9,447 |
|
|
16,319 |
|
CO2 operating and discovery expenses |
|
|
1,681 |
|
|
1,531 |
|
|
|
4,498 |
|
|
2,524 |
|
Taxes other than income |
|
|
36,317 |
|
|
22,382 |
|
|
|
67,698 |
|
|
41,345 |
|
Oil marketing purchases |
|
|
15,027 |
|
|
7,738 |
|
|
|
28,067 |
|
|
13,823 |
|
General and administrative expenses |
|
|
19,235 |
|
|
15,450 |
|
|
|
37,927 |
|
|
47,433 |
|
Interest, net of amounts capitalized of $975, $1,168, $2,133 and $2,251, respectively |
|
|
1,526 |
|
|
1,252 |
|
|
|
2,183 |
|
|
2,788 |
|
Depletion, depreciation, and amortization |
|
|
35,400 |
|
|
36,381 |
|
|
|
70,745 |
|
|
75,831 |
|
Commodity derivatives expense |
|
|
56,854 |
|
|
172,664 |
|
|
|
249,573 |
|
|
288,407 |
|
Write-down of oil and natural gas properties |
|
|
— |
|
|
— |
|
|
|
— |
|
|
14,377 |
|
Other expenses |
|
|
6,621 |
|
|
3,214 |
|
|
|
8,733 |
|
|
5,360 |
|
Total expenses |
|
|
301,814 |
|
|
379,359 |
|
|
|
721,050 |
|
|
700,402 |
|
Income (loss) before income taxes |
|
|
180,342 |
|
|
(77,991 |
) |
|
|
172,965 |
|
|
(147,875 |
) |
Income tax provision (benefit) |
|
|
|
|
|
|
|
|
||||||
Current income taxes |
|
|
2,912 |
|
|
(260 |
) |
|
|
2,351 |
|
|
(451 |
) |
Deferred income taxes |
|
|
21,936 |
|
|
(36 |
) |
|
|
15,992 |
|
|
(87 |
) |
Net income (loss) |
|
$ |
155,494 |
|
$ |
(77,695 |
) |
|
$ |
154,622 |
|
$ |
(147,337 |
) |
|
|
|
|
|
|
|
|
|
||||||
Net income (loss) per common share |
|
|
|
|
|
|
|
|
||||||
Basic |
|
$ |
3.00 |
|
$ |
(1.52 |
) |
|
$ |
2.99 |
|
$ |
(2.91 |
) |
Diluted |
|
$ |
2.83 |
|
$ |
(1.52 |
) |
|
$ |
2.81 |
|
$ |
(2.91 |
) |
|
|
|
|
|
|
|
|
|
||||||
Weighted average common shares outstanding |
|
|
|
|
|
|
|
|
||||||
Basic |
|
|
51,757 |
|
|
50,999 |
|
|
|
51,680 |
|
|
50,661 |
|
Diluted |
|
|
54,886 |
|
|
50,999 |
|
|
|
54,931 |
|
|
50,661 |
|
DENBURY INC. CONSOLIDATED STATEMENTS OF CASH FLOWS (UNAUDITED) |
||||||||||||||||
|
|
Quarter Ended |
|
Six Months Ended |
||||||||||||
|
|
June 30, |
|
June 30, |
||||||||||||
In thousands |
|
2022 |
|
2021 |
|
2022 |
|
2021 |
||||||||
Cash flows from operating activities |
|
|
|
|
|
|
|
|
||||||||
Net income (loss) |
|
$ |
155,494 |
|
|
$ |
(77,695 |
) |
|
$ |
154,622 |
|
|
$ |
(147,337 |
) |
Adjustments to reconcile net income (loss) to cash flows from operating activities |
|
|
|
|
|
|
|
|
||||||||
Depletion, depreciation, and amortization |
|
|
35,400 |
|
|
|
36,381 |
|
|
|
70,745 |
|
|
|
75,831 |
|
Write-down of oil and natural gas properties |
|
|
— |
|
|
|
— |
|
|
|
— |
|
|
|
14,377 |
|
Deferred income taxes |
|
|
21,936 |
|
|
|
(36 |
) |
|
|
15,992 |
|
|
|
(87 |
) |
Stock-based compensation |
|
|
4,104 |
|
|
|
2,552 |
|
|
|
7,075 |
|
|
|
20,232 |
|
Commodity derivatives expense |
|
|
56,854 |
|
|
|
172,664 |
|
|
|
249,573 |
|
|
|
288,407 |
|
Payment on settlements of commodity derivatives |
|
|
(127,959 |
) |
|
|
(63,343 |
) |
|
|
(221,016 |
) |
|
|
(101,796 |
) |
Debt issuance costs |
|
|
1,249 |
|
|
|
685 |
|
|
|
1,934 |
|
|
|
1,370 |
|
Other, net |
|
|
(1,888 |
) |
|
|
17 |
|
|
|
(3,155 |
) |
|
|
744 |
|
Changes in assets and liabilities, net of effects from acquisitions |
|
|
|
|
|
|
|
|
||||||||
Accrued production receivable |
|
|
(12,991 |
) |
|
|
(12,131 |
) |
|
|
(85,786 |
) |
|
|
(48,881 |
) |
Trade and other receivables |
|
|
(13,427 |
) |
|
|
(6,443 |
) |
|
|
(11,783 |
) |
|
|
(5,578 |
) |
Other current and long-term assets |
|
|
(12,364 |
) |
|
|
3,836 |
|
|
|
(12,175 |
) |
|
|
1,294 |
|
Accounts payable and accrued liabilities |
|
|
40,600 |
|
|
|
28,694 |
|
|
|
52,010 |
|
|
|
27,292 |
|
Oil and natural gas production payable |
|
|
9,981 |
|
|
|
7,429 |
|
|
|
33,329 |
|
|
|
20,224 |
|
Asset retirement obligations and other liabilities |
|
|
(7,024 |
) |
|
|
(1,728 |
) |
|
|
(11,257 |
) |
|
|
(2,554 |
) |
Net cash provided by operating activities |
|
|
149,965 |
|
|
|
90,882 |
|
|
|
240,108 |
|
|
|
143,538 |
|
|
|
|
|
|
|
|
|
|
||||||||
Cash flows from investing activities |
|
|
|
|
|
|
|
|
||||||||
Oil and natural gas capital expenditures |
|
|
(80,815 |
) |
|
|
(33,784 |
) |
|
|
(139,522 |
) |
|
|
(53,411 |
) |
CCUS storage sites and related capital expenditures |
|
|
(2,858 |
) |
|
|
— |
|
|
|
(17,758 |
) |
|
|
— |
|
Acquisitions of oil and natural gas properties |
|
|
(374 |
) |
|
|
(146 |
) |
|
|
(374 |
) |
|
|
(10,811 |
) |
Pipelines and plants capital expenditures |
|
|
(5,060 |
) |
|
|
(4,393 |
) |
|
|
(20,264 |
) |
|
|
(4,851 |
) |
Net proceeds from sales of oil and natural gas properties and equipment |
|
|
137 |
|
|
|
18,453 |
|
|
|
237 |
|
|
|
18,456 |
|
Other |
|
|
(4,127 |
) |
|
|
(1,243 |
) |
|
|
(5,623 |
) |
|
|
(4,159 |
) |
Net cash used in investing activities |
|
|
(93,097 |
) |
|
|
(21,113 |
) |
|
|
(183,304 |
) |
|
|
(54,776 |
) |
|
|
|
|
|
|
|
|
|
||||||||
Cash flows from financing activities |
|
|
|
|
|
|
|
|
||||||||
Bank repayments |
|
|
(250,000 |
) |
|
|
(283,000 |
) |
|
|
(524,000 |
) |
|
|
(485,000 |
) |
Bank borrowings |
|
|
215,000 |
|
|
|
243,000 |
|
|
|
489,000 |
|
|
|
450,000 |
|
Pipeline financing repayments |
|
|
— |
|
|
|
(17,001 |
) |
|
|
— |
|
|
|
(33,510 |
) |
Common stock repurchase program |
|
|
(23,374 |
) |
|
|
— |
|
|
|
(23,374 |
) |
|
|
— |
|
Other |
|
|
1,680 |
|
|
|
278 |
|
|
|
(1,388 |
) |
|
|
(2,735 |
) |
Net cash used in financing activities |
|
|
(56,694 |
) |
|
|
(56,723 |
) |
|
|
(59,762 |
) |
|
|
(71,245 |
) |
Net increase (decrease) in cash, cash equivalents, and restricted cash |
|
|
174 |
|
|
|
13,046 |
|
|
|
(2,958 |
) |
|
|
17,517 |
|
Cash, cash equivalents, and restricted cash at beginning of period |
|
|
47,212 |
|
|
|
46,719 |
|
|
|
50,344 |
|
|
|
42,248 |
|
Cash, cash equivalents, and restricted cash at end of period |
|
$ |
47,386 |
|
|
$ |
59,765 |
|
|
$ |
47,386 |
|
|
$ |
59,765 |
|
DENBURY INC. CONSOLIDATED BALANCE SHEETS (UNAUDITED) |
||||||||
In thousands, except par value and share data |
|
June 30, 2022 |
|
Dec. 31, 2021 |
||||
Assets |
|
|
|
|
||||
Current assets |
|
|
|
|
||||
Cash and cash equivalents |
|
$ |
517 |
|
|
$ |
3,671 |
|
Accrued production receivable |
|
|
229,151 |
|
|
|
143,365 |
|
Trade and other receivables, net |
|
|
30,918 |
|
|
|
19,270 |
|
Derivative assets |
|
|
2,829 |
|
|
|
— |
|
Prepaids |
|
|
18,686 |
|
|
|
9,099 |
|
Total current assets |
|
|
282,101 |
|
|
|
175,405 |
|
Property and equipment |
|
|
|
|
||||
Oil and natural gas properties (using full cost accounting) |
|
|
|
|
||||
Proved properties |
|
|
1,217,778 |
|
|
|
1,109,011 |
|
Unevaluated properties |
|
|
155,901 |
|
|
|
112,169 |
|
CO2 properties |
|
|
184,861 |
|
|
|
183,369 |
|
Pipelines |
|
|
226,318 |
|
|
|
224,394 |
|
CCUS storage sites and related assets |
|
|
24,026 |
|
|
|
— |
|
Other property and equipment |
|
|
98,777 |
|
|
|
93,950 |
|
Less accumulated depletion, depreciation, amortization and impairment |
|
|
(240,133 |
) |
|
|
(181,393 |
) |
Net property and equipment |
|
|
1,667,528 |
|
|
|
1,541,500 |
|
Operating lease right-of-use assets |
|
|
18,118 |
|
|
|
19,502 |
|
Derivative assets |
|
|
2,071 |
|
|
|
— |
|
Intangible assets, net |
|
|
83,688 |
|
|
|
88,248 |
|
Restricted cash for future asset retirement obligations |
|
|
46,869 |
|
|
|
46,673 |
|
Other assets |
|
|
38,305 |
|
|
|
31,625 |
|
Total assets |
|
$ |
2,138,680 |
|
|
$ |
1,902,953 |
|
Liabilities and Stockholders’ Equity |
|
|
|
|
||||
Current liabilities |
|
|
|
|
||||
Accounts payable and accrued liabilities |
|
$ |
262,752 |
|
|
$ |
191,598 |
|
Oil and gas production payable |
|
|
109,228 |
|
|
|
75,899 |
|
Derivative liabilities |
|
|
162,551 |
|
|
|
134,509 |
|
Operating lease liabilities |
|
|
4,670 |
|
|
|
4,677 |
|
Total current liabilities |
|
|
539,201 |
|
|
|
406,683 |
|
Long-term liabilities |
|
|
|
|
||||
Long-term debt, net of current portion |
|
|
— |
|
|
|
35,000 |
|
Asset retirement obligations |
|
|
273,852 |
|
|
|
284,238 |
|
Derivative liabilities |
|
|
5,415 |
|
|
|
— |
|
Deferred tax liabilities, net |
|
|
17,630 |
|
|
|
1,638 |
|
Operating lease liabilities |
|
|
15,571 |
|
|
|
17,094 |
|
Other liabilities |
|
|
18,170 |
|
|
|
22,910 |
|
Total long-term liabilities |
|
|
330,638 |
|
|
|
360,880 |
|
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; 50,875,988 and 50,193,656 shares issued, respectively |
|
|
51 |
|
|
|
50 |
|
Paid-in capital in excess of par |
|
|
1,137,575 |
|
|
|
1,129,996 |
|
Retained earnings |
|
|
159,966 |
|
|
|
5,344 |
|
Treasury stock, at cost, 457,549 and 0 shares, respectively |
|
|
(28,751 |
) |
|
|
— |
|
Total stockholders’ equity |
|
|
1,268,841 |
|
|
|
1,135,390 |
|
Total liabilities and stockholders’ equity |
|
$ |
2,138,680 |
|
|
$ |
1,902,953 |
|
DENBURY INC. OPERATING HIGHLIGHTS (UNAUDITED) |
||||||||||||
All sales volumes and dollars are expressed on a net revenue interest basis with gas volumes converted to equivalent barrels at 6:1. |
||||||||||||
|
|
Quarter Ended |
|
Six Months Ended |
||||||||
|
|
June 30, |
|
June 30, |
||||||||
|
|
2022 |
|
2021 |
|
2022 |
|
2021 |
||||
Average daily sales (BOE/d) |
|
|
|
|
|
|
|
|
||||
Tertiary |
|
|
|
|
|
|
|
|
||||
Gulf Coast region |
|
|
22,205 |
|
|
24,680 |
|
|
22,608 |
|
|
24,481 |
Rocky Mountain region |
|
|
9,186 |
|
|
8,772 |
|
|
9,203 |
|
|
7,984 |
Total tertiary sales |
|
|
31,391 |
|
|
33,452 |
|
|
31,811 |
|
|
32,465 |
|
|
|
|
|
|
|
|
|
||||
Non-tertiary |
|
|
|
|
|
|
|
|
||||
Gulf Coast region |
|
|
3,566 |
|
|
3,415 |
|
|
3,598 |
|
|
3,518 |
Rocky Mountain region |
|
|
11,604 |
|
|
12,266 |
|
|
11,333 |
|
|
12,267 |
Total non-tertiary sales |
|
|
15,170 |
|
|
15,681 |
|
|
14,931 |
|
|
15,785 |
|
|
|
|
|
|
|
|
|
||||
Total Company |
|
|
|
|
|
|
|
|
||||
Oil (Bbls/d) |
|
|
45,104 |
|
|
47,653 |
|
|
45,284 |
|
|
46,834 |
Natural gas (Mcf/d) |
|
|
8,741 |
|
|
8,882 |
|
|
8,747 |
|
|
8,494 |
BOE/d (6:1) |
|
|
46,561 |
|
|
49,133 |
|
|
46,742 |
|
|
48,250 |
|
|
|
|
|
|
|
|
|
||||
Unit sales price (excluding derivative settlements) |
|
|
|
|
|
|
|
|
||||
Gulf Coast region |
|
|
|
|
|
|
|
|
||||
Oil (per Bbl) |
|
$ |
108.87 |
|
$ |
64.90 |
|
$ |
100.94 |
|
$ |
60.72 |
Natural gas (per mcf) |
|
|
7.49 |
|
|
2.86 |
|
|
6.03 |
|
|
3.15 |
|
|
|
|
|
|
|
|
|
||||
Rocky Mountain region |
|
|
|
|
|
|
|
|
||||
Oil (per Bbl) |
|
$ |
108.72 |
|
$ |
64.44 |
|
$ |
101.07 |
|
$ |
60.40 |
Natural gas (per mcf) |
|
|
6.36 |
|
|
2.50 |
|
|
5.53 |
|
|
2.80 |
|
|
|
|
|
|
|
|
|
||||
Total Company |
|
|
|
|
|
|
|
|
||||
Oil (per Bbl)(1) |
|
$ |
108.81 |
|
$ |
64.70 |
|
$ |
101.00 |
|
$ |
60.59 |
Natural gas (per mcf) |
|
|
6.76 |
|
|
2.64 |
|
|
5.71 |
|
|
2.95 |
BOE (6:1) |
|
|
106.67 |
|
|
63.23 |
|
|
98.92 |
|
|
59.33 |
| (1) | Total company realized oil prices including derivative settlements were $77.63 per Bbl and $50.10 per Bbl during the three months ended June 30, 2022 and 2021, respectively, and $74.03 per Bbl and $48.58 per Bbl during the six months ended June 30, 2022 and 2021, 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 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. | ||||||||||||||||
|
|
Quarter Ended |
|
Quarter Ended |
||||||||||||
|
|
June 30, 2022 |
|
June 30, 2021 |
||||||||||||
In thousands, except per-share data |
|
Amount |
|
Per Diluted Share |
|
Amount |
|
Per Diluted Share |
||||||||
Net income (loss) (GAAP measure)(1) |
|
$ |
155,494 |
|
|
$ |
2.83 |
|
|
$ |
(77,695 |
) |
|
$ |
(1.52 |
) |
Adjustments to reconcile to adjusted net income (non-GAAP measure) |
|
|
|
|
|
|
|
|
||||||||
Noncash fair value losses (gains) on commodity derivatives(2) |
|
|
(71,105 |
) |
|
|
(1.30 |
) |
|
|
109,321 |
|
|
|
2.01 |
|
Delhi Field insurance reimbursements(3) |
|
|
(6,692 |
) |
|
|
(0.12 |
) |
|
|
— |
|
|
|
— |
|
Delta pipeline incident costs (included in other expenses)(4) |
|
|
3,867 |
|
|
|
0.07 |
|
|
|
— |
|
|
|
— |
|
Accrued litigation expense(5) |
|
|
1,444 |
|
|
|
0.03 |
|
|
|
— |
|
|
|
— |
|
Noncash fair value adjustment - contingent consideration(7) |
|
|
(12 |
) |
|
|
0.00 |
|
|
|
1,640 |
|
|
|
0.03 |
|
Adjustments to reconcile effect of dilutive securities(9) |
|
|
— |
|
|
|
— |
|
|
|
— |
|
|
|
0.09 |
|
Estimated income taxes on above adjustments to net income (loss) and other discrete tax items(10) |
|
|
10,005 |
|
|
|
0.18 |
|
|
|
— |
|
|
|
— |
|
Adjusted net income (non-GAAP measure) |
|
$ |
93,001 |
|
|
$ |
1.69 |
|
|
$ |
33,266 |
|
|
$ |
0.61 |
|
|
|
Six Months Ended |
|
Six Months Ended |
||||||||||||
|
|
June 30, 2022 |
|
June 30, 2021 |
||||||||||||
In thousands, except per-share data |
|
Amount |
|
Per Diluted Share |
|
Amount |
|
Per Diluted Share |
||||||||
Net income (loss) (GAAP measure)(1) |
|
|
154,622 |
|
|
$ |
2.81 |
|
|
|
(147,337 |
) |
|
$ |
(2.91 |
) |
Adjustments to reconcile to adjusted net income (non-GAAP measure) |
|
|
|
|
|
|
|
|
||||||||
Noncash fair value losses on commodity derivatives(2) |
|
|
28,557 |
|
|
|
0.52 |
|
|
|
186,611 |
|
|
|
3.54 |
|
Delhi Field insurance reimbursements(3) |
|
|
(6,692 |
) |
|
|
(0.12 |
) |
|
|
— |
|
|
|
— |
|
Delta pipeline incident costs (included in other expenses)(4) |
|
|
3,867 |
|
|
|
0.07 |
|
|
|
— |
|
|
|
— |
|
Accrued litigation expense(5) |
|
|
1,444 |
|
|
|
0.03 |
|
|
|
— |
|
|
|
— |
|
Write-down of oil and natural gas properties(6) |
|
|
— |
|
|
|
— |
|
|
|
14,377 |
|
|
|
0.27 |
|
Noncash fair value adjustment - contingent consideration(7) |
|
|
173 |
|
|
|
0.00 |
|
|
|
1,640 |
|
|
|
0.03 |
|
Other(8) |
|
|
— |
|
|
|
— |
|
|
|
325 |
|
|
|
0.01 |
|
Adjustments to reconcile effect of dilutive securities(9) |
|
|
— |
|
|
|
— |
|
|
|
— |
|
|
|
0.11 |
|
Estimated income taxes on above adjustments to net income (loss) and other discrete tax items(10) |
|
|
4,152 |
|
|
|
0.08 |
|
|
|
— |
|
|
|
— |
|
Adjusted net income (non-GAAP measure) |
|
$ |
186,123 |
|
|
$ |
3.39 |
|
|
$ |
55,616 |
|
|
$ |
1.05 |
|
(1) |
|
Diluted net income (loss) per common share includes the impact of potentially dilutive securities including nonvested restricted stock, restricted stock units, performance stock units and warrants. |
(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) |
|
Insurance reimbursements associated with a 2013 insurance claim related to property damage at Delhi Field. |
(4) |
|
Represents an accrual for a preliminarily assessed civil penalty proposed in May 2022 by the U.S. Department of Transportation’s Pipeline and Hazardous Materials Safety Administration related to the Company’s February 2020 Delta-Tinsley pipeline incident. |
(5) |
|
Represents accrued litigation expense, including $1 million recorded in other expenses and $0.4 million recorded in lease operating expenses during the three and six months ended June 30, 2022. |
(6) |
|
Full cost pool ceiling test write-downs related to the Company’s oil and natural gas properties. |
(7) |
|
Expense related to the change in fair value of the contingent consideration payments related to our March 2021 Wind River Basin CO2 EOR field acquisition. |
(8) |
|
Other adjustments primarily include <$1 million write-off of trade receivables during the three months ended March 31, 2021. |
(9) |
|
Represents the impact to the per-share calculation using weighted average dilutive shares of 54.3 million and 52.7 million during the three and six months ended June 30, 2021, respectively, as a result of the adjustments to the Company’s net loss (GAAP measure) to derive adjusted net income (non-GAAP measure). |
(10) |
|
The estimated income tax impacts on adjustments to net income for the three months ended June 30, 2022 are computed based upon a rate of 13.8% applied to income before tax, which incorporates discrete tax adjustments primarily comprised of the $18.8 million release of the valuation allowance. The income tax adjustment for the six months ended June 30, 2022 removes the impact of the valuation allowance reversed during the three months ended March 31, 2022. During the three months ended March 31, 2022, largely due to the significant increase in worldwide oil prices, the Company determined that it was no longer appropriate to carry a valuation allowance against certain of its federal and state deferred tax assets, as we now consider it more likely than not that we will realize those deferred tax assets. Accordingly, during the three and six months ended June 30, 2022, we reversed $18.8 million and $24.7 million of the valuation allowance, which lowered our deferred tax expense. In addition, we expect to reverse an additional $40.2 million of valuation allowance during the second half of 2022. |
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 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. |
|||||||||||||||
In thousands |
|
Quarter Ended |
|
Six Months Ended |
|||||||||||
|
June 30, |
|
June 30, |
||||||||||||
|
2022 |
|
2021 |
|
2022 |
|
2021 |
||||||||
Net income (loss) (GAAP measure) |
|
$ |
155,494 |
|
|
$ |
(77,695 |
) |
|
$ |
154,622 |
|
$ |
(147,337 |
) |
Adjustments to reconcile to Adjusted EBITDAX |
|
|
|
|
|
|
|
|
|||||||
Interest expense |
|
|
1,526 |
|
|
|
1,252 |
|
|
|
2,183 |
|
|
2,788 |
|
Income tax expense (benefit) |
|
|
24,848 |
|
|
|
(296 |
) |
|
|
18,343 |
|
|
(538 |
) |
Depletion, depreciation, and amortization |
|
|
35,400 |
|
|
|
36,381 |
|
|
|
70,745 |
|
|
75,831 |
|
Noncash fair value losses (gains) on commodity derivatives |
|
|
(71,105 |
) |
|
|
109,321 |
|
|
|
28,557 |
|
|
186,611 |
|
Stock-based compensation |
|
|
4,104 |
|
|
|
2,552 |
|
|
|
7,075 |
|
|
20,232 |
|
Write-down of oil and natural gas properties |
|
|
— |
|
|
|
— |
|
|
|
— |
|
|
14,377 |
|
Severance-related expense |
|
|
— |
|
|
|
476 |
|
|
|
— |
|
|
476 |
|
Noncash, non-recurring and other |
|
|
4,137 |
|
|
|
462 |
|
|
|
3,726 |
|
|
1,929 |
|
Adjusted EBITDAX (non-GAAP measure) |
|
$ |
154,404 |
|
|
$ |
72,453 |
|
|
$ |
285,251 |
|
$ |
154,369 |
|
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 oil and gas development expenditures, CCUS asset capital 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 sales volumes, 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. |
||||||||||||||||
In thousands |
|
Quarter Ended |
|
Six Months Ended |
||||||||||||
|
June 30, |
|
June 30, |
|||||||||||||
|
2022 |
|
2021 |
|
2022 |
|
2021 |
|||||||||
Cash flows from operations (GAAP measure) |
|
$ |
149,965 |
|
|
$ |
90,882 |
|
|
$ |
240,108 |
|
|
$ |
143,538 |
|
Net change in assets and liabilities relating to operations |
|
|
(4,775 |
) |
|
|
(19,657 |
) |
|
|
35,662 |
|
|
|
8,203 |
|
Adjusted cash flows from operations (non-GAAP measure) |
|
|
145,190 |
|
|
|
71,225 |
|
|
|
275,770 |
|
|
|
151,741 |
|
Oil & gas development expenditures |
|
|
(86,290 |
) |
|
|
(54,102 |
) |
|
|
(143,896 |
) |
|
|
(74,181 |
) |
CCUS storage sites and related capital expenditures |
|
|
(2,951 |
) |
|
|
— |
|
|
|
(23,900 |
) |
|
|
— |
|
Capitalized interest |
|
|
(975 |
) |
|
|
(1,168 |
) |
|
|
(2,133 |
) |
|
|
(2,251 |
) |
Free cash flow (non-GAAP measure) |
|
$ |
54,974 |
|
|
$ |
15,955 |
|
|
$ |
105,841 |
|
|
$ |
75,309 |
|
DENBURY INC. CAPITAL EXPENDITURE SUMMARY (UNAUDITED)(1) |
|||||||||||||
|
|
Quarter Ended |
|
Six Months Ended |
|||||||||
|
|
June 30, |
|
June 30, |
|||||||||
In thousands |
|
2022 |
|
2021 |
|
2022 |
|
2021 |
|||||
Capital expenditure summary |
|
|
|
|
|
|
|
|
|||||
CCA EOR field expenditures(2) |
|
$ |
21,483 |
|
|
$ |
9,091 |
|
$ |
39,205 |
|
$ |
9,100 |
CCA CO2 pipelines |
|
|
(950 |
) |
|
|
9,951 |
|
|
1,241 |
|
|
9,999 |
CCA tertiary development |
|
|
20,533 |
|
|
|
19,042 |
|
|
40,446 |
|
|
19,099 |
Non-CCA tertiary and non-tertiary fields |
|
|
57,074 |
|
|
|
27,875 |
|
|
86,437 |
|
|
40,297 |
CO2 sources and other CO2 pipelines |
|
|
1,380 |
|
|
|
— |
|
|
2,110 |
|
|
— |
Capitalized internal costs(3) |
|
|
7,303 |
|
|
|
7,185 |
|
|
14,903 |
|
|
14,785 |
Oil & gas development capital expenditures |
|
|
86,290 |
|
|
|
54,102 |
|
|
143,896 |
|
|
74,181 |
CCUS storage sites and related capital expenditures |
|
|
2,951 |
|
|
|
— |
|
|
23,900 |
|
|
— |
Acquisitions of oil and gas properties(4) |
|
|
3 |
|
|
|
146 |
|
|
374 |
|
|
10,811 |
Capitalized interest |
|
|
975 |
|
|
|
1,168 |
|
|
2,133 |
|
|
2,251 |
Total capital expenditures |
|
$ |
90,219 |
|
|
$ |
55,416 |
|
$ |
170,303 |
|
$ |
87,243 |
(1) |
Capital expenditure amounts incurred during the period, including accrued capital costs. |
|
(2) |
Includes pre-production CO2 costs associated with the CCA EOR development project totaling $8.0 million and $10.8 million during the three and six months ended June 30, 2022. |
|
(3) |
Includes capitalized internal acquisition, exploration and development costs and pre-production tertiary startup costs. |
|
(4) |
Primarily consists of working interest positions in the Wind River Basin enhanced oil recovery fields acquired on March 3, 2021. |
View source version on businesswire.com: https://www.businesswire.com/news/home/20220804005151/en/
Contacts
DENBURY IR CONTACTS:
Brad Whitmarsh, 972.673.2020, brad.whitmarsh@denbury.com
Beth Bierhaus, 972.673.2554, beth.bierhaus@denbury.com
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