HOUSTON--(BUSINESS WIRE)--Murphy Oil Corporation (NYSE: MUR) today announced its financial and operating results for the first quarter ended March 31, 2021, including a net loss attributable to Murphy of $287 million, or $1.87 net loss per diluted share. Excluding total after-tax charges of $297 million, comprised primarily of $128 million of non-cash asset impairments on the non-operated Terra Nova asset, $121 million unrealized non-cash mark-to-market losses on crude oil derivative contracts and $29 million cost of early redemption of debt, adjusted net income was $10 million, or $0.06 net income per diluted share.
Unless otherwise noted, the financial and operating highlights and metrics discussed in this commentary exclude noncontrolling interest. 1
Highlights for the first quarter include:
- Issued $550 million of 6.375 percent senior notes due 2028, and used proceeds and cash to redeem $576 million of senior notes due 2022
- Monetized the King’s Quay floating production system and fully repaid borrowings under the $1.6 billion senior unsecured credit facility
- Achieved total debt reduction of $233 million, or 8 percent, for the quarter from year-end 2020
- Produced 155 thousand barrels of oil equivalent per day, above the midpoint of guidance, with 88 thousand barrels of oil per day
- Acquired additional working interests in the non-operated Lucius field for $20 million, with expected payout in approximately one year
- Announced changes to the compensation program, including establishing a free cash flow metric and adding a greenhouse gas emissions reduction metric to the company’s Annual Incentive Plan
Subsequent to the first quarter, commenced drilling:
- The first well in the Khaleesi, Mormont, Samurai drilling program in the Gulf of Mexico, remaining on track for first oil in mid-2022
- The non-operated Silverback exploration well in the Gulf of Mexico, which will test a play-opening trend near existing Murphy-operated assets
“Murphy is off to a great start for the year, completing strategic financial transactions that delevered our balance sheet and extended our maturity profile. I am especially proud of our operational accomplishments across all of our assets, with a significant beat on oil production despite the severe winter storm in February. We remain in full execution mode on all of our Gulf of Mexico projects. Further, I am proud to see our exploration opportunities progress, with wells starting now in the Gulf of Mexico and later this year in Brazil,” said Roger W. Jenkins, President and Chief Executive Officer.
FIRST QUARTER 2021 RESULTS
The company recorded a net loss, attributable to Murphy, of $287 million, or $1.87 net loss per diluted share, for the first quarter 2021. This includes a realized after-tax loss on crude oil derivative contracts of $48 million. Adjusted net income, which excludes both the results of discontinued operations and certain other items that affect comparability of results between periods, was $10 million, or $0.06 net income per diluted share for the same period.
Adjusted earnings before interest, taxes, depreciation and amortization (EBITDA) from continuing operations attributable to Murphy was $255 million, or $18.65 per barrel of oil equivalent (BOE) sold. Adjusted earnings before interest, tax, depreciation, amortization and exploration expenses (EBITDAX) from continuing operations attributable to Murphy was $267 million, or $19.51 per BOE sold.
First quarter production averaged 155 thousand barrels of oil equivalent per day (MBOEPD) with 57 percent oil and 63 percent liquids. Details for first quarter results can be found in the attached schedules.
FINANCIAL POSITION
During the first quarter, Murphy issued $550 million of 6.375 percent senior notes due 2028. Proceeds, along with cash on hand, were used to redeem $259 million of senior notes due June 2022 and $317 million of senior notes due December 2022, totaling $576 million.
Overall, Murphy has reduced its total debt by $233 million, or 8 percent, from year-end 2020. Total debt of $2.756 billion consists of long-term, fixed-rate notes with a weighted average maturity of 7.7 years and a weighted average coupon of 6.3 percent.
Murphy had approximately $1.8 billion of liquidity, comprised of the $1.6 billion senior unsecured credit facility and approximately $231 million of cash and cash equivalents, at the end of the first quarter.
“As announced in March, we sold our 50 percent interest in the King’s Quay floating production system for $268 million in proceeds, which were used to fully repay borrowings on our credit facility. This transaction, in conjunction with our senior notes offering and redemption earlier in the month, allowed us to realize a meaningful debt reduction during the first quarter, completing the first step in our delevering goal and setting a path for further reductions later this year with current commodity prices,” stated Jenkins.
OPERATIONS SUMMARY
Onshore
The onshore business produced approximately 80 MBOEPD in the first quarter.
Eagle Ford Shale – Production averaged 30 MBOEPD with 74 percent oil volumes during the quarter. Murphy brought online 16 operated wells in Karnes and achieved an average gross 30-day (IP30) rate of approximately 1,400 BOEPD, with the two best wells achieving approximately 2,000 BOEPD IP30 rates in the Lower Eagle Ford Shale. Most significantly, a three-well pad targeting the Austin Chalk zone has meaningfully outperformed Murphy’s expectations, with production averaging approximately 1,400 BOEPD IP30 rate.
Murphy also had 12 non-operated Karnes wells and four non-operated Tilden wells come online during the quarter.
Tupper Montney – In the first quarter, natural gas production averaged 234 million cubic feet per day (MMCFPD). The company brought online four wells as planned.
Kaybob Duvernay – First quarter production averaged 9 MBOEPD with 74 percent liquids volumes. No activity is scheduled to occur in 2021.
Offshore
The offshore business produced 76 MBOEPD for the first quarter, comprised of 79 percent oil. This excludes production from noncontrolling interest and an asset held for sale.
Gulf of Mexico – During the quarter, production averaged 71 MBOEPD, consisting of 78 percent oil. Murphy completed certain operated and non-operated subsea equipment repairs as previously disclosed, and all wells were brought back online. Additionally, the non-operated Lucius 918 #3 and Lucius 919 #9 wells in Keathley Canyon came online during the quarter, and the non-operated Kodiak #3 well (Mississippi Canyon 727) was completed, with first oil achieved in the second quarter 2021.
Murphy increased its working interest in the Lucius field to 12.7 percent from 9.2 percent for $20 million, providing incremental production of approximately 1.1 MBOEPD for the quarter with an expected payback time of approximately one year. Major projects continued to progress, with the drilling program launching at Khaleesi, Mormont, Samurai in early second quarter. In addition, the first producer well for the St. Malo waterflood was brought online during the first quarter, and drilling began on the final well of the four-well campaign in early second quarter.
Canada – Production averaged 5 MBOEPD in the first quarter, comprised of 100 percent oil. Operations at the Terra Nova field have remained offline since December 2019. During first quarter 2021, Murphy recorded a non-cash after-tax impairment charge of $128 million on the asset due to the current status of operating and production plans. Partners continue to evaluate options that could support a long-term production plan.
EXPLORATION
Gulf of Mexico – Subsequent to quarter-end, Murphy and its operating partner spud the Silverback exploration well (Mississippi Canyon 35).
“In late April, our partner spud the Silverback well in the Gulf of Mexico. This well will test an attractive new play-opening trend and, if successful, could provide additional high-potential opportunities to our large adjacent acreage position,” stated Jenkins.
CAPITAL EXPENDITURE AND PRODUCTION GUIDANCE
Murphy maintains its 2021 capital expenditures (CAPEX) guidance of $675 to $725 million and is tightening full year 2021 production to the range of 157 to 165 MBOEPD. Full year production is forecast to be comprised of approximately 54 percent oil and 60 percent total liquids volumes. Production for second quarter 2021 is estimated to be in the range of 160 to 168 MBOEPD. Both production and CAPEX guidance ranges exclude Gulf of Mexico noncontrolling interest (NCI).
CAPEX by Quarter ($ MMs) |
||||
1Q 2021A* |
2Q 2021E |
3Q 2021E |
4Q 2021E |
FY 2021E |
$230 |
$190 |
$160 |
$120 |
$700 |
Accrual CAPEX, based on midpoint of guidance range and excluding NCI
* Excludes King’s Quay CAPEX of $17 million, includes $20 million Lucius working interest acquisition
“We remain on track for executing our 2021 program within our original stated capital guidance,” stated Jenkins. “I am pleased with the success we have achieved in the first quarter, especially with capital efficiencies and production, along with our offshore projects moving forward according to plan. This allows us to focus on generating free cash flow to continue delevering and return cash to shareholders through our longstanding dividend.”
CONFERENCE CALL AND WEBCAST SCHEDULED FOR MAY 6, 2021
Murphy will host a conference call to discuss first quarter 2021 financial and operating results on Thursday, May 6, 2021, at 9:00 a.m. EDT. The call can be accessed either via the Internet through the Investor Relations section of Murphy Oil’s website at http://ir.murphyoilcorp.com or via the telephone by dialing toll free 1-888-886-7786, reservation number 41671800.
FINANCIAL DATA
Summary financial data and operating statistics for first quarter 2021, with comparisons to the same period from the previous year, are contained in the following schedules. Additionally, a schedule indicating the impacts of items affecting comparability of results between periods, a reconciliation of EBITDA and EBITDAX between periods, as well as guidance for the second quarter and full year 2021, are also included.
1In accordance with GAAP, Murphy reports the 100 percent interest, including a 20 percent noncontrolling interest (NCI), in its subsidiary, MP Gulf of Mexico, LLC (MP GOM). The GAAP financials include the NCI portion of revenue, costs, assets and liabilities and cash flows. Unless otherwise noted, the financial and operating highlights and metrics discussed in this news release, but not the accompanying schedules, exclude the NCI, thereby representing only the amounts attributable to Murphy.
ABOUT MURPHY OIL CORPORATION
As an independent oil and natural gas exploration and production company, Murphy Oil Corporation believes in providing energy that empowers people by doing right always, staying with it and thinking beyond possible. Murphy challenges the norm, taps into its strong legacy and uses its foresight and financial discipline to deliver inspired energy solutions. The company sees a future where it is an industry leader who is positively impacting lives for the next 100 years and beyond. Additional information can be found on the company’s website at www.murphyoilcorp.com.
FORWARD-LOOKING STATEMENTS
This news release contains forward-looking statements within the meaning of the Private Securities Litigation Reform Act of 1995. Forward-looking statements are generally identified through the inclusion of words such as “aim”, “anticipate”, “believe”, “drive”, “estimate”, “expect”, “expressed confidence”, “forecast”, “future”, “goal”, “guidance”, “intend”, “may”, “objective”, “outlook”, “plan”, “position”, “potential”, “project”, “seek”, “should”, “strategy”, “target”, “will” or variations of such words and other similar expressions. These statements, which express management’s current views concerning future events or results, are subject to inherent risks and uncertainties. Factors that could cause one or more of these future events or results not to occur as implied by any forward-looking statement include, but are not limited to: macro conditions in the oil and gas industry, including supply/demand levels, actions taken by major oil exporters and the resulting impacts on commodity prices; increased volatility or deterioration in the success rate of our exploration programs or in our ability to maintain production rates and replace reserves; reduced customer demand for our products due to environmental, regulatory, technological or other reasons; adverse foreign exchange movements; political and regulatory instability in the markets where we do business; the impact on our operations or market of health pandemics such as COVID-19 and related government responses; other natural hazards impacting our operations or markets; any other deterioration in our business, markets or prospects; any failure to obtain necessary regulatory approvals; any inability to service or refinance our outstanding debt or to access debt markets at acceptable prices; or adverse developments in the U.S. or global capital markets, credit markets or economies in general. For further discussion of factors that could cause one or more of these future events or results not to occur as implied by any forward-looking statement, see “Risk Factors” in our most recent Annual Report on Form 10-K filed with the U.S. Securities and Exchange Commission (“SEC”) and any subsequent Quarterly Report on Form 10-Q or Current Report on Form 8-K that we file, available from the SEC’s website and from Murphy Oil Corporation’s website at http://ir.murphyoilcorp.com. Murphy Oil Corporation undertakes no duty to publicly update or revise any forward-looking statements.
NON-GAAP FINANCIAL MEASURES
This news release contains certain non-GAAP financial measures that management believes are useful tools for internal use and the investment community in evaluating Murphy Oil Corporation’s overall financial performance. These non-GAAP financial measures are broadly used to value and compare companies in the crude oil and natural gas industry. Not all companies define these measures in the same way. In addition, these non-GAAP financial measures are not a substitute for financial measures prepared in accordance with GAAP and should therefore be considered only as supplemental to such GAAP financial measures. Please see the attached schedules for reconciliations of the differences between the non-GAAP financial measures used in this news release and the most directly comparable GAAP financial measures.
MURPHY OIL CORPORATION |
||||||
SUMMARIZED CONSOLIDATED STATEMENTS OF OPERATIONS (unaudited) |
||||||
|
Three Months Ended March 31, |
|||||
(Thousands of dollars, except per share amounts) |
2021 |
|
2020 |
|||
Revenues and other income |
|
|
|
|||
Revenue from sales to customers |
$ |
592,527 |
|
|
600,558 |
|
(Loss) gain on crude contracts |
(214,385 |
) |
|
400,672 |
|
|
Gain on sale of assets and other income |
1,843 |
|
|
2,498 |
|
|
Total revenues and other income |
379,985 |
|
|
1,003,728 |
|
|
Costs and expenses |
|
|
|
|||
Lease operating expenses |
147,164 |
|
|
209,148 |
|
|
Severance and ad valorem taxes |
9,231 |
|
|
9,422 |
|
|
Transportation, gathering and processing |
42,912 |
|
|
44,367 |
|
|
Exploration expenses, including undeveloped lease amortization |
11,780 |
|
|
20,126 |
|
|
Selling and general expenses |
29,503 |
|
|
36,772 |
|
|
Depreciation, depletion and amortization |
198,278 |
|
|
306,102 |
|
|
Accretion of asset retirement obligations |
10,492 |
|
|
9,966 |
|
|
Impairment of assets |
171,296 |
|
|
967,530 |
|
|
Other expense (benefit) |
21,079 |
|
|
(45,188 |
) |
|
Total costs and expenses |
641,735 |
|
|
1,558,245 |
|
|
Operating loss from continuing operations |
(261,750 |
) |
|
(554,517 |
) |
|
Other income (loss) |
|
|
|
|||
Interest and other income (loss) |
(5,341 |
) |
|
241 |
|
|
Interest expense, net |
(88,100 |
) |
|
(41,097 |
) |
|
Total other loss |
(93,441 |
) |
|
(40,856 |
) |
|
Loss from continuing operations before income taxes |
(355,191 |
) |
|
(595,373 |
) |
|
Income tax benefit |
(88,159 |
) |
|
(91,533 |
) |
|
Loss from continuing operations |
(267,032 |
) |
|
(503,840 |
) |
|
Income (loss) from discontinued operations, net of income taxes |
208 |
|
|
(4,862 |
) |
|
Net loss including noncontrolling interest |
(266,824 |
) |
|
(508,702 |
) |
|
Less: Net income (loss) attributable to noncontrolling interest |
20,614 |
|
|
(92,598 |
) |
|
NET LOSS ATTRIBUTABLE TO MURPHY |
$ |
(287,438 |
) |
|
(416,104 |
) |
|
|
|
|
|||
LOSS PER COMMON SHARE – BASIC |
|
|
|
|||
Continuing operations |
$ |
(1.87 |
) |
|
(2.68 |
) |
Discontinued operations |
— |
|
|
(0.03 |
) |
|
Net loss |
$ |
(1.87 |
) |
|
(2.71 |
) |
|
|
|
|
|||
LOSS PER COMMON SHARE – DILUTED |
|
|
|
|||
Continuing operations |
$ |
(1.87 |
) |
|
(2.68 |
) |
Discontinued operations |
— |
|
|
(0.03 |
) |
|
Net loss |
$ |
(1.87 |
) |
|
(2.71 |
) |
Cash dividends per Common share |
0.125 |
|
|
0.25 |
|
|
Average Common shares outstanding (thousands) |
|
|
|
|||
Basic |
153,953 |
|
|
153,313 |
|
|
Diluted |
153,953 |
|
|
153,313 |
|
|
MURPHY OIL CORPORATION |
||||||
CONSOLIDATED STATEMENTS OF CASH FLOWS (unaudited) |
||||||
|
Three Months Ended March 31, |
|||||
(Thousands of dollars) |
2021 |
|
2020 |
|||
Operating Activities |
|
|
|
|||
Net loss including noncontrolling interest |
$ |
(266,824 |
) |
|
(508,702 |
) |
Adjustments to reconcile net loss to net cash provided by continuing operations activities |
|
|
|
|||
(Income) loss from discontinued operations |
(208 |
) |
|
4,862 |
|
|
Depreciation, depletion and amortization |
198,278 |
|
|
306,102 |
|
|
Previously suspended exploration costs |
717 |
|
|
97 |
|
|
Amortization of undeveloped leases |
4,602 |
|
|
7,478 |
|
|
Accretion of asset retirement obligations |
10,492 |
|
|
9,966 |
|
|
Impairment of assets |
171,296 |
|
|
967,530 |
|
|
Deferred income tax benefit |
(88,867 |
) |
|
(81,373 |
) |
|
Mark to market loss (gain) on contingent consideration |
14,923 |
|
|
(59,151 |
) |
|
Mark to market loss (gain) on crude contracts |
153,505 |
|
|
(358,302 |
) |
|
Long-term non-cash compensation |
12,124 |
|
|
9,805 |
|
|
Net (increase) decrease in noncash working capital |
(9,052 |
) |
|
107,827 |
|
|
Other operating activities, net |
36,780 |
|
|
(13,482 |
) |
|
Net cash provided by continuing operations activities |
237,766 |
|
|
392,657 |
|
|
Investing Activities |
|
|
|
|||
Property additions and dry hole costs |
(240,545 |
) |
|
(354,834 |
) |
|
Property additions for King's Quay FPS |
(17,734 |
) |
|
(21,296 |
) |
|
Proceeds from sales of property, plant and equipment |
268,023 |
|
|
— |
|
|
Net cash provided (required) by investing activities |
9,744 |
|
|
(376,130 |
) |
|
Financing Activities |
|
|
|
|||
Borrowings on revolving credit facility |
140,000 |
|
|
170,000 |
|
|
Repayment of revolving credit facility |
(340,000 |
) |
|
— |
|
|
Retirement of debt |
(576,358 |
) |
|
(3,570 |
) |
|
Debt issuance, net of cost |
541,980 |
|
|
(613 |
) |
|
Early redemption of debt cost |
(34,177 |
) |
|
— |
|
|
Distributions to noncontrolling interest |
(36,006 |
) |
|
(32,399 |
) |
|
Cash dividends paid |
(19,287 |
) |
|
(38,392 |
) |
|
Withholding tax on stock-based incentive awards |
(3,794 |
) |
|
(7,094 |
) |
|
Capital lease obligation payments |
(178 |
) |
|
(168 |
) |
|
Net cash (required) provided by financing activities |
(327,820 |
) |
|
87,764 |
|
|
Cash Flows from Discontinued Operations 1 |
|
|
|
|||
Operating activities |
— |
|
|
(1,202 |
) |
|
Investing activities |
— |
|
|
4,494 |
|
|
Financing activities |
— |
|
|
— |
|
|
Net cash provided by discontinued operations |
— |
|
|
3,292 |
|
|
Effect of exchange rate changes on cash and cash equivalents |
574 |
|
|
(3,298 |
) |
|
Net (decrease) increase in cash and cash equivalents |
(79,736 |
) |
|
100,993 |
|
|
Cash and cash equivalents at beginning of period |
310,606 |
|
|
306,760 |
|
|
Cash and cash equivalents at end of period |
$ |
230,870 |
|
|
407,753 |
|
1 Net cash provided by discontinued operations is not part of the cash flow reconciliation.
MURPHY OIL CORPORATION |
||||||
SCHEDULE OF ADJUSTED INCOME (LOSS) (unaudited) |
||||||
|
Three Months Ended March 31, |
|||||
(Millions of dollars, except per share amounts) |
2021 |
|
2020 |
|||
Net loss attributable to Murphy (GAAP) |
$ |
(287.4 |
) |
|
(416.1 |
) |
Discontinued operations (income) loss |
(0.2 |
) |
|
4.9 |
|
|
Loss from continuing operations |
(287.6 |
) |
|
(411.2 |
) |
|
Adjustments (after tax): |
|
|
|
|||
Impairment of assets |
128.0 |
|
|
692.7 |
|
|
Mark-to-market loss (gain) on crude oil derivative contracts |
121.3 |
|
|
(283.1 |
) |
|
Early redemption of debt cost |
29.2 |
|
|
— |
|
|
Mark-to-market loss (gain) on contingent consideration |
11.8 |
|
|
(46.7 |
) |
|
Charges related to Kings Quay transaction |
3.9 |
|
|
— |
|
|
Unutilized rig charges |
2.2 |
|
|
2.8 |
|
|
Foreign exchange losses (gains) |
0.9 |
|
|
(4.0 |
) |
|
Inventory loss |
— |
|
|
3.8 |
|
|
Total adjustments after taxes |
297.3 |
|
|
365.5 |
|
|
Adjusted income (loss) from continuing operations attributable to Murphy |
$ |
9.7 |
|
|
(45.7 |
) |
|
|
|
|
|||
Adjusted income (loss) from continuing operations per average diluted share |
$ |
0.06 |
|
|
(0.30 |
) |
Non-GAAP Financial Measures
Presented above is a reconciliation of Net (loss) income to Adjusted (loss) income from continuing operations attributable to Murphy. Adjusted (loss) income excludes certain items that management believes affect the comparability of results between periods. Management believes this is important information to provide because it is used by management to evaluate the Company’s operational performance and trends between periods and relative to its industry competitors. Management also believes this information may be useful to investors and analysts to gain a better understanding of the Company’s financial results. Adjusted (loss) income is a non-GAAP financial measure and should not be considered a substitute for Net (loss) income as determined in accordance with accounting principles generally accepted in the United States of America.
Amounts shown above as reconciling items between Net (loss) income and Adjusted (loss) income are presented net of applicable income taxes based on the estimated statutory rate in the applicable tax jurisdiction. The pretax and income tax impacts for adjustments shown above are as follows by area of operations and exclude the share attributable to non-controlling interests.
|
Three Months Ended March 31, 2021 |
||||||||
(Millions of dollars) |
Pretax |
|
Tax |
|
Net |
||||
Exploration & Production: |
|
|
|
|
|
||||
United States |
$ |
22.7 |
|
|
(4.8) |
|
|
17.9 |
|
Canada |
|
171.3 |
|
|
(43.3) |
|
|
128.0 |
|
Total E&P |
|
194.0 |
|
|
(48.1) |
|
|
145.9 |
|
Corporate: |
|
191.7 |
|
|
(40.3) |
|
|
151.4 |
|
Total adjustments |
$ |
385.7 |
|
|
(88.4) |
|
|
297.3 |
|
MURPHY OIL CORPORATION |
||||||
SCHEDULE OF EARNINGS BEFORE INTEREST, TAXES, DEPRECIATION |
||||||
AND AMORTIZATION (EBITDA) |
||||||
(unaudited) |
||||||
|
Three Months Ended March 31, |
|||||
(Millions of dollars, except per barrel of oil equivalents sold) |
2021 |
|
2020 |
|||
Net loss attributable to Murphy (GAAP) |
$ |
(287.4 |
) |
|
(416.1 |
) |
Income tax benefit |
(88.2 |
) |
|
(91.5 |
) |
|
Interest expense, net |
88.1 |
|
|
41.1 |
|
|
Depreciation, depletion and amortization expense ¹ |
188.3 |
|
|
286.2 |
|
|
EBITDA attributable to Murphy (Non-GAAP) |
(99.2 |
) |
|
(180.3 |
) |
|
Impairment of assets ¹ |
171.3 |
|
|
866.4 |
|
|
Mark-to-market loss (gain) on crude oil derivative contracts |
153.5 |
|
|
(358.3 |
) |
|
Mark-to-market loss (gain) on contingent consideration |
14.9 |
|
|
(59.2 |
) |
|
Accretion of asset retirement obligations |
10.5 |
|
|
10.0 |
|
|
Unutilized rig charges |
2.8 |
|
|
3.5 |
|
|
Foreign exchange losses (gains) |
1.3 |
|
|
(4.7 |
) |
|
Discontinued operations (income) loss |
(0.2 |
) |
|
4.9 |
|
|
Inventory loss |
— |
|
|
4.8 |
|
|
Adjusted EBITDA attributable to Murphy (Non-GAAP) |
$ |
254.9 |
|
|
287.1 |
|
|
|
|
|
|||
Total barrels of oil equivalents sold from continuing operations attributable to Murphy (thousands of barrels) |
13,670 |
|
|
17,071 |
|
|
|
|
|
|
|||
Adjusted EBITDA per barrel of oil equivalents sold |
$ |
18.65 |
|
|
16.82 |
|
1 Depreciation, depletion, and amortization expense used in the computation of EBITDA excludes the portion attributable to the non-controlling interest (NCI). Impairment of assets used in the computation of Adjusted EBITDA excludes the portion attributable to the non-controlling interest.
Non-GAAP Financial Measures
Presented above is a reconciliation of Net (loss) income to Earnings before interest, taxes, depreciation and amortization (EBITDA) and adjusted EBITDA. Management believes EBITDA and adjusted EBITDA are important information to provide because they are used by management to evaluate the Company’s operational performance and trends between periods and relative to its industry competitors. Management also believes this information may be useful to investors and analysts to gain a better understanding of the Company’s financial results. EBITDA and adjusted EBITDA are non-GAAP financial measures and should not be considered a substitute for Net (loss) income or Cash provided by operating activities as determined in accordance with accounting principles generally accepted in the United States of America.
Presented above is adjusted EBITDA per barrel of oil equivalent sold. Management believes adjusted EBITDA per barrel of oil equivalent sold is important information because it is used by management to evaluate the Company’s profitability of one barrel of oil equivalent sold in that period. Adjusted EBITDA per barrel of oil equivalent sold is a non-GAAP financial metric.
MURPHY OIL CORPORATION |
||||||
SCHEDULE OF EARNINGS BEFORE INTEREST, TAXES, DEPRECIATION |
||||||
AND AMORTIZATION AND EXPLORATION (EBITDAX) |
||||||
(unaudited) |
||||||
|
Three Months Ended March 31, |
|||||
(Millions of dollars, except per barrel of oil equivalents sold) |
2021 |
|
2020 |
|||
Net loss attributable to Murphy (GAAP) |
$ |
(287.4 |
) |
|
(416.1 |
) |
Income tax benefit |
(88.2 |
) |
|
(91.5 |
) |
|
Interest expense, net |
88.1 |
|
|
41.1 |
|
|
Depreciation, depletion and amortization expense ¹ |
188.3 |
|
|
286.2 |
|
|
EBITDA attributable to Murphy (Non-GAAP) |
(99.2 |
) |
|
(180.3 |
) |
|
Exploration expenses |
11.8 |
|
|
20.1 |
|
|
EBITDAX attributable to Murphy (Non-GAAP) |
(87.4 |
) |
|
(160.2 |
) |
|
Impairment of assets ¹ |
171.3 |
|
|
866.4 |
|
|
Mark-to-market loss (gain) on crude oil derivative contracts |
153.5 |
|
|
(358.3 |
) |
|
Mark-to-market loss (gain) on contingent consideration |
14.9 |
|
|
(59.2 |
) |
|
Accretion of asset retirement obligations |
10.5 |
|
|
10.0 |
|
|
Unutilized rig charges |
2.8 |
|
|
3.5 |
|
|
Foreign exchange losses (gains) |
1.3 |
|
|
(4.7 |
) |
|
Discontinued operations (income) loss |
(0.2 |
) |
|
4.9 |
|
|
Inventory loss |
— |
|
|
4.8 |
|
|
Adjusted EBITDAX attributable to Murphy (Non-GAAP) |
$ |
266.7 |
|
|
307.2 |
|
|
|
|
|
|||
Total barrels of oil equivalents sold from continuing operations attributable to Murphy (thousands of barrels) |
13,670 |
|
|
17,071 |
|
|
|
|
|
|
|||
Adjusted EBITDAX per barrel of oil equivalents sold |
$ |
19.51 |
|
|
17.99 |
|
1 Depreciation, depletion, and amortization expense used in the computation of EBITDAX excludes the portion attributable to the non-controlling interest. Impairment of assets used in the computation of Adjusted EBITDAX excludes the portion attributable to the non-controlling interest.
Non-GAAP Financial Measures
Presented above is a reconciliation of Net (loss) income to Earnings before interest, taxes, depreciation and amortization, and exploration expenses (EBITDAX) and adjusted EBITDAX. Management believes EBITDAX and adjusted EBITDAX are important information to provide because they are used by management to evaluate the Company’s operational performance and trends between periods and relative to its industry competitors. Management also believes this information may be useful to investors and analysts to gain a better understanding of the Company’s financial results. EBITDAX and adjusted EBITDAX are non-GAAP financial measures and should not be considered a substitute for Net (loss) income or Cash provided by operating activities as determined in accordance with accounting principles generally accepted in the United States of America.
Presented above is adjusted EBITDAX per barrel of oil equivalent sold. Management believes adjusted EBITDAX per barrel of oil equivalent sold is important information because it is used by management to evaluate the Company’s profitability of one barrel of oil equivalent sold in that period. Adjusted EBITDAX per barrel of oil equivalent sold is a non-GAAP financial metric.
MURPHY OIL CORPORATION |
|||||||||
FUNCTIONAL RESULTS OF OPERATIONS (unaudited) |
|||||||||
|
Three Months Ended March 31, 2021 |
Three Months Ended March 31, 2020 |
|||||||
(Millions of dollars) |
Revenues |
Income (Loss) |
Revenues |
Income (Loss) |
|||||
Exploration and production |
|
|
|
|
|||||
United States1 |
$ |
490.3 |
|
119.0 |
|
511.5 |
|
(696.0 |
) |
Canada |
104.0 |
|
(124.3 |
) |
89.7 |
|
(6.9 |
) |
|
Other |
— |
|
(6.9 |
) |
1.8 |
|
(52.3 |
) |
|
Total exploration and production |
594.3 |
|
(12.2 |
) |
603.0 |
|
(755.2 |
) |
|
Corporate |
(214.3 |
) |
(254.8 |
) |
400.7 |
|
251.4 |
|
|
Revenue/loss from continuing operations |
380.0 |
|
(267.0 |
) |
1,003.7 |
|
(503.8 |
) |
|
Discontinued operations, net of tax |
— |
|
0.2 |
|
— |
|
(4.9 |
) |
|
Total revenues/net loss including noncontrolling interest |
$ |
380.0 |
|
(266.8 |
) |
1,003.7 |
|
(508.7 |
) |
Net loss attributable to Murphy |
|
(287.4 |
) |
|
(416.1 |
) |
|||
1 Includes results attributable to a noncontrolling interest in MP Gulf of Mexico, LLC (MP GOM).
MURPHY OIL CORPORATION |
|||||||||
OIL AND GAS OPERATING RESULTS (unaudited) |
|||||||||
THREE MONTHS ENDED MARCH 31, 2021, AND 2020 |
|||||||||
(Millions of dollars) |
United States 1 |
Canada |
Other |
Total |
|||||
Three Months Ended March 31, 2021 |
|
|
|
|
|||||
Oil and gas sales and other operating revenues |
$ |
490.3 |
|
104.0 |
|
— |
|
594.3 |
|
Lease operating expenses |
116.1 |
|
30.8 |
|
0.3 |
|
147.2 |
|
|
Severance and ad valorem taxes |
8.9 |
|
0.3 |
|
— |
|
9.2 |
|
|
Transportation, gathering and processing |
28.5 |
|
14.4 |
|
— |
|
42.9 |
|
|
Depreciation, depletion and amortization |
149.6 |
|
44.8 |
|
0.5 |
|
194.9 |
|
|
Accretion of asset retirement obligations |
9.0 |
|
1.5 |
|
— |
|
10.5 |
|
|
Impairment of assets |
— |
|
171.3 |
|
— |
|
171.3 |
|
|
Exploration expenses |
|
|
|
|
|||||
Dry holes and previously suspended exploration costs |
0.7 |
|
— |
|
— |
|
0.7 |
|
|
Geological and geophysical |
0.6 |
|
— |
|
0.2 |
|
0.8 |
|
|
Other exploration |
0.6 |
|
— |
|
5.0 |
|
5.6 |
|
|
|
1.9 |
|
— |
|
5.2 |
|
7.1 |
|
|
Undeveloped lease amortization |
2.3 |
|
0.1 |
|
2.2 |
|
4.6 |
|
|
Total exploration expenses |
4.2 |
|
0.1 |
|
7.4 |
|
11.7 |
|
|
Selling and general expenses |
5.5 |
|
4.1 |
|
1.4 |
|
11.0 |
|
|
Other |
21.5 |
|
3.1 |
|
(3.5 |
) |
21.1 |
|
|
Results of operations before taxes |
147.0 |
|
(166.4 |
) |
(6.1 |
) |
(25.5 |
) |
|
Income tax provisions (benefits) |
28.0 |
|
(42.1 |
) |
0.8 |
|
(13.3 |
) |
|
Results of operations (excluding Corporate segment) |
$ |
119.0 |
|
(124.3 |
) |
(6.9 |
) |
(12.2 |
) |
|
|
|
|
|
|||||
Three Months Ended March 31, 2020 |
|
|
|
|
|||||
Oil and gas sales and other operating revenues |
$ |
511.5 |
|
89.7 |
|
1.8 |
|
603.0 |
|
Lease operating expenses |
178.2 |
|
30.6 |
|
0.3 |
|
209.1 |
|
|
Severance and ad valorem taxes |
9.1 |
|
0.3 |
|
— |
|
9.4 |
|
|
Transportation, gathering and processing |
34.6 |
|
9.8 |
|
— |
|
44.4 |
|
|
Depreciation, depletion and amortization |
247.5 |
|
52.0 |
|
0.5 |
|
300.0 |
|
|
Accretion of asset retirement obligations |
8.6 |
|
1.4 |
|
— |
|
10.0 |
|
|
Impairment of assets |
927.8 |
|
— |
|
39.7 |
|
967.5 |
|
|
Exploration expenses |
|
|
|
|
|||||
Dry holes and previously suspended exploration costs |
0.1 |
|
— |
|
— |
|
0.1 |
|
|
Geological and geophysical |
1.3 |
|
— |
|
3.7 |
|
5.0 |
|
|
Other exploration |
0.8 |
|
0.2 |
|
6.5 |
|
7.5 |
|
|
|
2.2 |
|
0.2 |
|
10.2 |
|
12.6 |
|
|
Undeveloped lease amortization |
5.1 |
|
0.2 |
|
2.2 |
|
7.5 |
|
|
Total exploration expenses |
7.3 |
|
0.4 |
|
12.4 |
|
20.1 |
|
|
Selling and general expenses |
3.7 |
|
4.4 |
|
1.6 |
|
9.7 |
|
|
Other |
(45.7 |
) |
0.2 |
|
(1.2 |
) |
(46.7 |
) |
|
Results of operations before taxes |
(859.6 |
) |
(9.4 |
) |
(51.5 |
) |
(920.5 |
) |
|
Income tax provisions (benefits) |
(163.6 |
) |
(2.5 |
) |
0.8 |
|
(165.3 |
) |
|
Results of operations (excluding Corporate segment) |
$ |
(696.0 |
) |
(6.9 |
) |
(52.3 |
) |
(755.2 |
) |
1 Includes results attributable to a noncontrolling interest in MP GOM.
MURPHY OIL CORPORATION |
||||||
PRODUCTION-RELATED EXPENSES |
||||||
(unaudited) |
||||||
|
Three Months Ended March 31, |
|||||
(Dollars per barrel of oil equivalents sold) |
2021 |
|
2020 |
|||
Continuing operations |
|
|
|
|||
United States – Eagle Ford Shale |
|
|
|
|||
Lease operating expense |
$ |
10.80 |
|
|
10.47 |
|
Severance and ad valorem taxes |
3.13 |
|
|
2.42 |
|
|
Depreciation, depletion and amortization (DD&A) expense |
28.45 |
|
|
25.03 |
|
|
|
|
|
|
|||
United States – Gulf of Mexico |
|
|
|
|||
Lease operating expense 1 |
12.30 |
|
|
15.03 |
|
|
Severance and ad valorem taxes |
0.08 |
|
|
— |
|
|
DD&A expense |
10.37 |
|
|
16.58 |
|
|
|
|
|
|
|||
Canada – Onshore |
|
|
|
|||
Lease operating expense |
5.72 |
|
|
4.45 |
|
|
Severance and ad valorem taxes |
0.08 |
|
|
0.06 |
|
|
DD&A expense |
8.90 |
|
|
9.65 |
|
|
|
|
|
|
|||
Canada – Offshore |
|
|
|
|||
Lease operating expense 2 |
17.00 |
|
|
19.53 |
|
|
DD&A expense |
16.00 |
|
|
12.09 |
|
|
|
|
|
|
|||
Total oil and gas continuing operations |
|
|
|
|||
Lease operating expense |
10.11 |
|
|
11.41 |
|
|
Severance and ad valorem taxes |
0.63 |
|
|
0.51 |
|
|
DD&A expense |
13.62 |
|
|
16.70 |
|
|
|
|
|
|
|||
Total oil and gas continuing operations – excluding noncontrolling interest |
|
|
|
|||
Lease operating expense 3 |
9.75 |
|
|
11.05 |
|
|
Severance and ad valorem taxes |
0.67 |
|
|
0.55 |
|
|
DD&A expense |
13.78 |
|
|
16.76 |
|
|
1 For the three months ended March 31, 2021, lease operating expense (LOE) per barrel of oil equivalents (BOE) sold for the U.S. Gulf of Mexico excluding cost associated with well workovers was $8.41. Workovers for the three months ended March 31, 2021 principally relate to St. Malo.
2 For the three months ended March 31, 2021 and 2020, Canada Offshore LOE per BOE excluding the costs associated with the Terra Nova life extension project was $9.17 and $5.29, respectively.
3 For the three months ended March 31, 2021, total LOE per BOE excluding NCI and costs associated with Gulf of Mexico well workovers was $8.09. Workovers for the three months ended March 31, 2021 principally relate to St. Malo.
MURPHY OIL CORPORATION |
||||||
OTHER FINANCIAL DATA |
||||||
(unaudited) |
||||||
|
Three Months Ended March 31, |
|||||
(Millions of dollars) |
2021 |
|
2020 |
|||
Capital expenditures for continuing operations |
|
|
|
|||
Exploration and production |
|
|
|
|||
United States |
$ |
211.1 |
|
|
245.4 |
|
Canada |
30.6 |
|
|
108.2 |
|
|
Other |
5.6 |
|
|
20.9 |
|
|
Total |
247.3 |
|
|
374.5 |
|
|
|
|
|
|
|||
Corporate |
3.8 |
|
|
3.5 |
|
|
Total capital expenditures - continuing operations 1 |
251.1 |
|
|
378.0 |
|
|
|
|
|
|
|||
Charged to exploration expenses 2 |
|
|
|
|||
United States |
1.9 |
|
|
2.2 |
|
|
Canada |
— |
|
|
0.2 |
|
|
Other |
5.2 |
|
|
10.2 |
|
|
Total charged to exploration expenses - continuing operations |
7.1 |
|
|
12.6 |
|
|
|
|
|
|
|||
Total capitalized |
$ |
244.0 |
|
|
365.4 |
|
1 For the three months ended March 31, 2021 and 2020, includes noncontrolling interest (NCI) capital expenditures of $3.6 million and $10.3 million, respectively. Also, for the three months ended March 31, 2021 and 2020, includes capital expenditures associated with the King’s Quay project of $17.2 million and $28.8 million, respectively. King’s Quay was sold to ArcLight Capital Partners, LLC (ArcLight) on March 17, 2021 for proceeds of $267.7 million which reimburses the Company for previously incurred capital expenditures.
2 Excludes amortization of undeveloped leases of $4.6 million and $7.5 million for the three months ended March 31, 2021 and 2020, respectively.
MURPHY OIL CORPORATION |
||||||
CONSOLIDATED BALANCE SHEETS |
||||||
(unaudited) |
||||||
(Millions of dollars) |
March 31,
|
|
December 31,
|
|||
ASSETS |
|
|
|
|||
Current assets |
|
|
|
|||
Cash and cash equivalents |
$ |
230.9 |
|
|
310.6 |
|
Accounts receivable |
|
278.8 |
|
|
262.0 |
|
Inventories |
|
66.6 |
|
|
66.1 |
|
Prepaid expenses |
|
37.6 |
|
|
33.9 |
|
Assets held for sale |
|
77.4 |
|
|
327.7 |
|
Total current assets |
|
691.3 |
|
|
1,000.3 |
|
Property, plant and equipment, at cost |
|
8,216.7 |
|
|
8,269.0 |
|
Operating lease assets |
|
911.9 |
|
|
927.7 |
|
Deferred income taxes |
|
433.6 |
|
|
395.3 |
|
Deferred charges and other assets |
|
30.8 |
|
|
28.6 |
|
Total assets |
$ |
10,284.3 |
|
|
10,620.9 |
|
LIABILITIES AND EQUITY |
|
|
|
|||
Current liabilities |
|
|
|
|||
Accounts payable |
$ |
538.3 |
|
|
407.1 |
|
Income taxes payable |
|
17.4 |
|
|
18.0 |
|
Other taxes payable |
|
18.0 |
|
|
22.5 |
|
Operating lease liabilities |
|
103.0 |
|
|
103.8 |
|
Other accrued liabilities |
|
174.6 |
|
|
150.6 |
|
Liabilities associated with assets held for sale |
|
14.1 |
|
|
14.4 |
|
Total current liabilities |
|
865.4 |
|
|
716.3 |
|
Long-term debt |
|
2,755.6 |
|
|
2,988.1 |
|
Asset retirement obligations |
|
904.1 |
|
|
816.3 |
|
Deferred credits and other liabilities |
|
691.3 |
|
|
680.6 |
|
Non-current operating lease liabilities |
|
829.8 |
|
|
845.1 |
|
Deferred income taxes |
|
138.7 |
|
|
180.3 |
|
Total liabilities |
|
6,184.7 |
|
|
6,226.7 |
|
Equity |
|
|
|
|||
Common Stock, par $1.00 |
|
195.1 |
|
|
195.1 |
|
Capital in excess of par value |
|
914.3 |
|
|
941.7 |
|
Retained earnings |
|
5,062.8 |
|
|
5,369.5 |
|
Accumulated other comprehensive loss |
|
(575.6 |
) |
|
(601.3 |
) |
Treasury stock |
|
(1,661.4 |
) |
|
(1,690.7 |
) |
Murphy Shareholders' Equity |
|
3,935.2 |
|
|
4,214.3 |
|
Noncontrolling interest |
|
164.4 |
|
|
179.8 |
|
Total equity |
|
4,099.6 |
|
|
4,394.1 |
|
Total liabilities and equity |
$ |
10,284.3 |
|
|
10,620.9 |
|
MURPHY OIL CORPORATION |
||||||
PRODUCTION SUMMARY |
||||||
(unaudited) |
||||||
|
|
Three Months Ended March 31, |
||||
Barrels per day unless otherwise noted |
2021 |
|
2020 |
|||
Continuing operations |
|
|
|
|
||
Net crude oil and condensate |
|
|
|
|||
United States |
Onshore |
22,165 |
|
|
31,033 |
|
|
Gulf of Mexico 1 |
64,363 |
|
|
78,730 |
|
Canada |
Onshore |
6,288 |
|
|
6,833 |
|
|
Offshore |
4,589 |
|
|
5,138 |
|
Other |
|
70 |
|
|
344 |
|
Total net crude oil and condensate - continuing operations |
97,475 |
|
|
122,078 |
|
|
Net natural gas liquids |
|
|
|
|
||
United States |
Onshore |
3,933 |
|
|
5,585 |
|
|
Gulf of Mexico 1 |
4,679 |
|
|
6,670 |
|
Canada |
Onshore |
1,233 |
|
|
1,401 |
|
Total net natural gas liquids - continuing operations |
9,845 |
|
|
13,656 |
|
|
Net natural gas – thousands of cubic feet per day |
|
|
|
|||
United States |
Onshore |
22,016 |
|
|
31,962 |
|
|
Gulf of Mexico 1 |
72,658 |
|
|
81,950 |
|
Canada |
Onshore |
253,697 |
|
|
266,848 |
|
Total net natural gas - continuing operations |
348,371 |
|
|
380,760 |
|
|
Total net hydrocarbons - continuing operations including NCI 2,3 |
165,382 |
|
|
199,194 |
|
|
Noncontrolling interest |
|
|
|
|
||
Net crude oil and condensate – barrels per day |
(9,174 |
) |
|
(12,020 |
) |
|
Net natural gas liquids – barrels per day |
(354 |
) |
|
(559 |
) |
|
Net natural gas – thousands of cubic feet per day 2 |
(4,159 |
) |
|
(5,091 |
) |
|
Total noncontrolling interest |
(10,221 |
) |
|
(13,428 |
) |
|
Total net hydrocarbons - continuing operations excluding NCI 2,3 |
155,161 |
|
|
185,767 |
|
|
1 Includes net volumes attributable to a noncontrolling interest in MP GOM.
2 Natural gas converted on an energy equivalent basis of 6:1.
3 NCI – noncontrolling interest in MP GOM.
MURPHY OIL CORPORATION |
||||||||
PRICE SUMMARY |
||||||||
(unaudited) |
||||||||
|
|
Three Months Ended March 31, |
||||||
|
|
2021 |
|
2020 |
||||
Weighted average Exploration and Production sales prices |
|
|
|
|||||
Continuing operations |
|
|
|
|
||||
Crude oil and condensate – dollars per barrel |
|
|
|
|
||||
United States |
Onshore |
$ |
57.41 |
|
|
$ |
46.46 |
|
|
Gulf of Mexico 1 |
58.78 |
|
|
47.07 |
|
||
Canada 2 |
Onshore |
52.84 |
|
|
37.61 |
|
||
|
Offshore |
59.39 |
|
|
57.27 |
|
||
Other |
|
— |
|
|
65.55 |
|||
Natural gas liquids – dollars per barrel |
|
|
|
|
||||
United States |
Onshore |
21.25 |
|
|
10.79 |
|
||
|
Gulf of Mexico 1 |
23.87 |
|
|
8.28 |
|
||
Canada 2 |
Onshore |
35.92 |
|
|
15.96 |
|
||
Natural gas – dollars per thousand cubic feet |
|
|
|
|
||||
United States |
Onshore |
3.27 |
|
|
1.85 |
|
||
|
Gulf of Mexico 1 |
3.39 |
|
|
2.01 |
|
||
Canada 2 |
Onshore |
2.26 |
|
|
1.62 |
|
||
1 Prices include the effect of noncontrolling interest share for MP GOM.
2 U.S. dollar equivalent.
MURPHY OIL CORPORATION |
|||||||||||||
COMMODITY HEDGE POSITIONS (unaudited) |
|||||||||||||
AS OF MAY 4, 2021 |
|||||||||||||
|
|
Commodity |
|
Type |
|
Volumes (Bbl/d) |
|
Price (USD/Bbl) |
|
Remaining Period |
|||
Area |
|
|
|
|
|
Start Date |
|
End Date |
|||||
United States |
|
WTI ¹ |
|
Fixed price derivative swap |
|
45,000 |
|
|
$42.77 |
|
4/1/2021 |
|
12/31/2021 |
United States |
|
WTI ¹ |
|
Fixed price derivative swap |
|
20,000 |
|
|
$44.88 |
|
1/1/2022 |
|
12/31/2022 |
1 West Texas Intermediate
|
|
|
|
|
|
Volumes (MMcf/d) |
|
Price (CAD/Mcf) |
|
Remaining Period |
|||
Area |
|
Commodity |
|
Type |
|
|
|
Start Date |
|
End Date |
|||
Montney |
|
Natural Gas |
|
Fixed price forward sales at AECO |
|
203 |
|
|
C$2.55 |
|
4/1/2021 |
|
5/31/2021 |
Montney |
|
Natural Gas |
|
Fixed price forward sales at AECO |
|
241 |
|
|
C$2.57 |
|
6/1/2021 |
|
12/31/2021 |
Montney |
|
Natural Gas |
|
Fixed price forward sales at AECO |
|
231 |
|
|
C$2.42 |
|
1/1/2022 |
|
1/31/2022 |
Montney |
|
Natural Gas |
|
Fixed price forward sales at AECO |
|
221 |
|
|
C$2.41 |
|
2/1/2022 |
|
4/30/2022 |
Montney |
|
Natural Gas |
|
Fixed price forward sales at AECO |
|
250 |
|
|
C$2.40 |
|
5/1/2022 |
|
5/31/2022 |
Montney |
|
Natural Gas |
|
Fixed price forward sales at AECO |
|
292 |
|
|
C$2.39 |
|
6/1/2022 |
|
12/31/2022 |
Montney |
|
Natural Gas |
|
Fixed price forward sales at AECO |
|
201 |
|
|
C$2.36 |
|
1/1/2023 |
|
12/31/2023 |
Montney |
|
Natural Gas |
|
Fixed price forward sales at AECO |
|
147 |
|
|
C$2.41 |
|
1/1/2024 |
|
12/31/2024 |
MURPHY OIL CORPORATION |
|||||||
SECOND QUARTER 2021 GUIDANCE |
|||||||
|
Oil BOPD |
|
NGLs BOPD |
|
Gas MCFD |
|
Total BOEPD |
Production – net |
|
|
|
|
|
|
|
U.S. – Eagle Ford Shale |
28,300 |
|
5,000 |
|
27,400 |
|
37,900 |
– Gulf of Mexico excluding NCI |
57,400 |
|
5,100 |
|
68,800 |
|
74,000 |
Canada – Tupper Montney |
— |
|
— |
|
236,400 |
|
39,400 |
– Kaybob Duvernay and Placid Montney |
5,400 |
|
1,000 |
|
18,200 |
|
9,400 |
– Offshore |
3,300 |
|
— |
|
— |
|
3,300 |
|
|
|
|
|
|
|
|
Total net production (BOEPD) - excluding NCI 1 |
160,000 to 168,000 |
||||||
|
|
|
|
|
|
|
|
Exploration expense ($ millions) |
$20 |
||||||
|
|
|
|
|
|
|
|
FULL YEAR 2021 GUIDANCE |
|||||||
Total net production (BOEPD) - excluding NCI 2 |
157,000 to 165,000 |
||||||
Capital expenditures – excluding NCI ($ millions) 3 |
$675 to $725 |
||||||
|
|
||||||
¹ Excludes noncontrolling interest of MP GOM of 9,500 BOPD of oil, 600 BOPD of NGLs, and 4,600 MCFD gas. |
|||||||
² Excludes noncontrolling interest of MP GOM of 8,800 BOPD of oil, 500 BOPD of NGLs, and 4,300 MCFD gas. |
|||||||
³ Excludes noncontrolling interest of MP GOM of $30 MM. |
|||||||
