mur-20201105
false000071742300007174232020-11-052020-11-05

UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
FORM 8-K
CURRENT REPORT
PURSUANT TO SECTION 13 OR 15(d) OF THE
SECURITIES EXCHANGE ACT OF 1934
Date of report (Date of earliest event reported): November 5, 2020
MURPHY OIL CORPORATION
(Exact name of registrant as specified in its charter)
Delaware1-859071-0361522
(State or other jurisdiction of incorporation)(Commission File Number)(I.R.S. Employer Identification No.)
9805 Katy Fwy, Suite G-200
Houston,Texas77024
(Address of principal executive offices, including zip code)
(281)
675-9000
Registrant’s telephone number, including area code
Not applicable
(Former Name or Former Address, if Changed Since Last Report)

Check the appropriate box below if the Form 8-K filing is intended to simultaneously satisfy the filing obligation of the registrant under any of the following provisions (see General Instruction A.2. below):
Written communications pursuant to Rule 425 under the Securities Act (17 CFR 230.425)

Soliciting material pursuant to Rule 14a-12 under the Exchange Act (17 CFR 240.14a-12)

Pre-commencement communications pursuant to Rule 14d-2(b) under the Exchange Act (17 CFR 240.14d-2(b))

Pre-commencement communications pursuant to Rule 13e-4(c) under the Exchange Act (17 CFR 240.13e-4(c))

Securities registered pursuant to Section 12(b) of the Act:
 Title of each classTrading SymbolName of each exchange on which registered
Common Stock, $1.00 Par ValueMURNew York Stock Exchange
Indicate by check mark whether the registrant is an emerging growth company as defined in Rule 405 of the Securities Act of 1933 (§230.405 of this chapter) or Rule 12b-2 of the Securities Exchange Act of 1934 (§240.12b-2 of this chapter).                                             Emerging growth company
If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act.                                               
    



Item 2.02.   Results of Operations and Financial Condition
The following information is furnished pursuant to Item 2.02, “Results of Operations and Financial Condition.”
On November 5, 2020 Murphy Oil Corporation issued a news release announcing its financial and operating results for the quarter ended September 30, 2020.    The full text of this news release is attached hereto as Exhibit 99.1.
Item 9.01.  Financial Statements and Exhibits
(d)Exhibits




Signature
Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned hereunto duly authorized.
MURPHY OIL CORPORATION
Date: November 5, 2020

By:
/s/ Christopher D. Hulse

Christopher D. Hulse

Vice President and Controller



Exhibit Index
Exhibit
No.
101. INSXBRL Instance Document

101. SCHXBRL Taxonomy Extension Schema Document

101. CALXBRL Taxonomy Extension Calculation Linkbase Document

101. DEFXBRL Taxonomy Extension Definition Linkbase Document

101. LABXBRL Taxonomy Extension Labels Linkbase Document

101. PREXBRL Taxonomy Extension Presentation Linkbase


Document

EXHIBIT 99.1

MURPHY OIL CORPORATION ANNOUNCES THIRD QUARTER 2020
OPERATING AND FINANCIAL RESULTS
Expanded Hedge Coverage, Published 2020 Sustainability Report
HOUSTON, Texas, November 5, 2020 – Murphy Oil Corporation (NYSE: MUR) today announced its financial and operating results for the third quarter ended September 30, 2020, including a net loss attributable to Murphy of $244 million, or $1.59 net loss per diluted share. Adjusted net loss, which excludes discontinued operations and other one-off items, was $24 million, or $0.15 net loss per diluted share.
Unless otherwise noted, the financial and operating highlights and metrics discussed in this commentary exclude noncontrolling interest. 1
Significant items include:
Produced 153 thousand barrels of oil equivalent per day in the third quarter, including 56 percent or 86 thousand barrels of oil per day, despite the most severe hurricane season on record
Continued G&A reduction trajectory, with expenses of $29 million in the third quarter compared to $39 million in second quarter 2020
Increased 2021 crude oil hedge position, resulting in a total of 18 thousand barrels of oil per day hedged at an average price of $43.31 per barrel
Added fixed price forward sales contracts related to the Tupper Montney asset to underpin cash flow in calendar years 2021 through 2024
Published 2020 Sustainability Report, with expanded disclosures and greenhouse gas emissions intensity reduction goals







1


THIRD QUARTER 2020 FINANCIAL RESULTS
The company recorded a net loss, attributable to Murphy, of $244 million, or $1.59 net loss per diluted share, for the third quarter 2020. Adjusted net loss, which excludes both the results of discontinued operations and certain other items that affect comparability of results between periods, was $24 million, or $0.15 net loss per diluted share for the same period. The adjusted loss from continuing operations primarily excludes the following after-tax items: a $55 million non-cash mark-to-market loss on crude oil derivative contracts and an $11 million non-cash mark-to-market loss on liabilities associated with contingent consideration. It also includes an after-tax $146 million non-cash charge for the impairment of certain assets primarily related to the Cascade and Chinook field in the Gulf of Mexico. Details for third quarter results can be found in the attached schedules.
Adjusted earnings before interest, taxes, depreciation and amortization (EBITDA) from continuing operations attributable to Murphy was $249 million, or $17.61 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 $262 million, or $18.46 per BOE sold. Details for third quarter adjusted EBITDA and EBITDAX reconciliations can be found in the attached schedules.
Third quarter production averaged 153 thousand barrels of oil equivalent per day (MBOEPD) with 56 percent oil and 63 percent liquids. Murphy’s offshore production for the quarter was negatively impacted by an uncharacteristically active hurricane season, resulting in 12.4 MBOEPD of storm-related downtime, compared to 4.8 MBOEPD as guided for storm downtime. Offshore storm downtime was partially offset by stronger performance in the onshore business. Details for third quarter production can be found in the attached schedules.
“Murphy, like all Gulf of Mexico operators, experienced the most severe hurricane season on record this year with four major storms during the third quarter causing short-term production shut-ins, as well as two additional storms following in October. Our assets generated strong production aside from these storms and otherwise would have reached the high end of guidance. Our cost structure improvements continue to take hold leading to improving margins. Further, we were able to safely execute evacuating and re-manning processes of our facilities, along with managing COVID-19 concerns with our proven shore base protocols,” stated Roger W. Jenkins, President and Chief Executive Officer of Murphy Oil Corporation.
2


PROTECTING THE COMPANY’S FINANCIAL POSITION
As of September 30, 2020, Murphy had approximately $1.6 billion of liquidity, comprised of $1.4 billion undrawn under the $1.6 billion senior unsecured credit facility and approximately $220 million of cash and cash equivalents.
At the end of third quarter 2020, Murphy had outstanding debt of $2.8 billion in long-term, fixed-rate notes with a weighted average maturity of 7 years and a weighted average coupon of 5.9 percent. The company also had $200 million drawn under its senior unsecured credit facility.
For third quarter 2020, Murphy incurred a total $120 million of CAPEX, including approximately $19 million for the King’s Quay floating production system (FPS) construction. Note that this total CAPEX figure excludes Gulf of Mexico noncontrolling interest (NCI). Murphy incurred a total $663 million of CAPEX for the nine months ended September 30, 2020, including $81 million for King’s Quay.
The company generated free cash flow of $74 million in the third quarter, including NCI. Excluding the impact of a working capital outflow of $28 million, free cash flow was $102 million.
COMMODITY HEDGE POSITIONS MITIGATE CASH FLOW VOLATILITY
The company employs commodity derivative instruments to manage certain risks associated with commodity price volatility and underpin capital returns associated with certain assets. During the third quarter, Murphy layered on hedges to protect cash flow with the execution of WTI fixed price swaps, resulting in a total 18 thousand barrels of oil per day (MBOPD) hedged for full year 2021 at an average price of $43.31 per barrel. Also during the quarter, the company entered into fixed price forward sales contracts for the delivery of 20 million cubic feet per day (MMCFD) at the Malin hub in Oregon at an average price of $2.60 per thousand cubic feet (MCF) for calendar years 2021 and 2022.
Subsequent to quarter end, Murphy entered into fixed price forward sales contracts for physical delivery at the AECO hub in Canada for calendar year 2021, resulting in total contracts of 96 MMCFD at an average price of C$2.53 per MCF. Murphy further extended its price protection with fixed price forward sales contracts at AECO for full years 2022 through 2024 for the delivery of 71 MMCFD at an average price of C$2.50 per MCF.
3


Details for the current hedge positions can be found in the attached schedules.
FOURTH QUARTER 2020 GUIDANCE
Murphy reaffirms its previously stated full year 2020 capital budget guidance of $680 million to $720 million, excluding Gulf of Mexico NCI and King’s Quay floating production system (FPS) construction spending. In the fourth quarter, Murphy anticipates production volumes of approximately 146 MBOEPD to 154 MBOEPD. This guidance range is primarily affected by two factors – Gulf of Mexico storm downtime of 8.2 MBOEPD due to impacts from hurricanes Delta and Zeta, as well as 6.4 MBOEPD of planned downtime.
OPERATIONS SUMMARY
North American Onshore
The North American onshore business produced approximately 90 MBOEPD in the third quarter. No operated drilling and completions activity is planned across the onshore business for the remainder of 2020.
Eagle Ford Shale – Production averaged 35 MBOEPD with 71 percent oil volumes in the third quarter. As planned, eight non-operated Karnes wells came online in the quarter. Murphy’s operating partner plans to drill four Karnes wells during the fourth quarter, with completions anticipated in early 2021.
Tupper Montney – For the quarter, natural gas production averaged 235 MMCFD. No drilling or completions activity occurred in the third quarter.
Kaybob Duvernay – Production averaged 13 MBOEPD in the third quarter. Four wells were brought online during the quarter.
Placid Montney – Murphy’s non-operated position produced 3 MBOEPD in the third quarter. As previously disclosed, six non-operated wells resumed production in July after being shut in for May and June due to low commodity prices.
Global Offshore
The offshore business produced 63 MBOEPD in the third quarter, comprised of 82 percent oil. This excludes production from discontinued operations and noncontrolling interest. Gulf of Mexico production in the quarter averaged 59 MBOEPD, consisting of 80 percent oil. Canada offshore production averaged 4 MBOEPD, comprised of 100 percent oil.
4


EXPLORATION
Gulf of Mexico – The non-operated Highgarden well (Green Canyon 895) was spud in the third quarter for an estimated $11 million cost net to Murphy as a 20 percent working interest owner. Drilling was delayed due to an active Gulf of Mexico storm season.
SUSTAINABILITY REPORT
Subsequent to quarter-end, Murphy published its 2020 Sustainability Report, taking into consideration various third-party reporting standards and ratings, and including additional disclosures spanning climate-related performance metrics to workforce diversity. As part of this report, the company announced its goal of reducing its greenhouse gas emissions intensity by 15 to 20 percent by 2030 from 2019 levels, excluding Malaysia.
CONFERENCE CALL AND WEBCAST SCHEDULED FOR NOVEMBER 5, 2020
Murphy will host a conference call to discuss third quarter 2020 financial and operating results on Thursday, November 5, 2020, at 9:00 a.m. ET. 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 19218031.
FINANCIAL DATA
Summary financial data and operating statistics for third quarter 2020, 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 fourth quarter 2020, are also included.
1 In 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.
5


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. It challenges the norm, taps into its strong legacy and uses its foresight and financial discipline to deliver inspired energy solutions. Murphy 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
6


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.
Investor Contacts:
Kelly Whitley, kelly_whitley@murphyoilcorp.com, 281-675-9107
Megan Larson, megan_larson@murphyoilcorp.com, 281-675-9470


7


MURPHY OIL CORPORATION
SUMMARIZED CONSOLIDATED STATEMENTS OF OPERATIONS (unaudited)
Three Months Ended
September 30,
Nine Months Ended
September 30,
(Thousands of dollars, except per share amounts)
20202019 20202019
Revenues and other income
Revenue from sales to customers$425,324 750,337 1,311,627 2,060,127 
(Loss) gain on crude contracts(5,290)63,247 319,502 121,163 
Gain on sale of assets and other income1,831 3,493 6,006 10,283 
Total revenues and other income421,865 817,077 1,637,135 2,191,573 
Costs and expenses
Lease operating expenses124,491 147,632 478,283 416,460 
Severance and ad valorem taxes6,781 13,803 22,645 36,972 
Transportation, gathering and processing41,322 54,305 126,779 128,748 
Exploration expenses, including undeveloped lease amortization12,092 12,358 61,686 75,570 
Selling and general expenses28,509 55,366 104,381 176,258 
Restructuring expenses4,982 — 46,379 — 
Depreciation, depletion and amortization231,603 325,562 769,151 819,270 
Accretion of asset retirement obligations10,778 10,587 31,213 29,824 
Impairment of assets219,138 — 1,206,284 — 
Other (benefit) expense20,224 (29,000)(2,957)26,442 
Total costs and expenses699,920 590,613 2,843,844 1,709,544 
Operating (loss) income from continuing operations(278,055)226,464 (1,206,709)482,029 
Other (loss)
Interest and other (loss)(5,177)(4,418)(10,107)(18,134)
Interest expense, net(45,182)(44,930)(124,877)(145,095)
Total other (loss)(50,359)(49,348)(134,984)(163,229)
(Loss) income from continuing operations before income taxes(328,414)177,116 (1,341,693)318,800 
Income tax (benefit) expense(62,584)18,782 (248,890)38,719 
(Loss) income from continuing operations(265,830)158,334 (1,092,803)280,081 
(Loss) income from discontinued operations, net of income taxes(778)953,368 (6,907)1,027,632 
Net (loss) income including noncontrolling interest(266,608)1,111,702 (1,099,710)1,307,713 
Less: Net (loss) income attributable to noncontrolling interest(23,055)22,700 (122,869)86,257 
NET (LOSS) INCOME ATTRIBUTABLE TO MURPHY$(243,553)1,089,002 (976,841)1,221,456 
(LOSS) INCOME PER COMMON SHARE – BASIC
Continuing operations$(1.58)0.85 (6.31)1.16 
Discontinued operations(0.01)5.94 (0.05)6.14 
Net (loss) income$(1.59)6.79 (6.36)7.30 
(LOSS) INCOME PER COMMON SHARE – DILUTED
Continuing operations$(1.58)0.84 (6.31)1.16 
Discontinued operations(0.01)5.92 (0.05)6.11 
Net (loss) income$(1.59)6.76 (6.36)7.27 
Cash dividends per Common share0.125 0.25 0.50 0.75 
Average Common shares outstanding (thousands)
Basic153,596 160,366 153,480 167,310 
Diluted153,596 160,980 153,480 168,105 

8


MURPHY OIL CORPORATION
CONSOLIDATED STATEMENTS OF CASH FLOWS (unaudited)
Three Months Ended
September 30,
Nine Months Ended
September 30,
(Thousands of dollars)
20202019 20202019
Operating Activities
Net (loss) income including noncontrolling interest$(266,608)1,111,702 (1,099,710)1,307,713 
Adjustments to reconcile net (loss) income to net cash provided by continuing operations activities:
Loss (income) from discontinued operations778 (953,368)6,907 (1,027,632)
Depreciation, depletion and amortization231,603 325,562 769,151 819,270 
Previously suspended exploration costs578 — 8,255 12,901 
Amortization of undeveloped leases7,181 6,530 21,951 21,680 
Accretion of asset retirement obligations10,778 10,587 31,213 29,824 
Impairment of assets219,138 — 1,206,284 — 
Deferred income tax (benefit) expense(63,846)32,596 (231,748)50,597 
Mark to market (gain) loss on contingent consideration14,053 (28,378)(29,476)512 
Mark to market (gain) loss of crude contracts
69,385 (49,245)(104,463)(100,076)
Noncash restructuring expense— — 17,565 — 
Long-term non-cash compensation12,440 15,812 35,200 60,567 
Net decrease (increase) in noncash operating working capital(27,596)45,623 (26,261)40,257 
Other operating activities, net768 (19,274)(26,837)(62,386)
Net cash provided by continuing operations activities208,652 497,796 578,031 1,153,227 
Investing Activities
Property additions and dry hole costs(111,124)(350,340)(648,725)(995,509)
Property additions for King's Quay FPS(23,301)(13,637)(74,936)(13,637)
Acquisition of oil and gas properties— 13,312 — (1,212,949)
Proceeds from sales of property, plant and equipment— 2,256 — 19,072 
Net cash required by investing activities(134,425)(348,409)(723,661)(2,203,023)
Financing Activities
Borrowings on revolving credit facility80,000 500,000 450,000 1,575,000 
Repayment of revolving credit facility(50,000)(1,900,000)(250,000)(1,900,000)
Cash dividends paid(19,200)(39,934)(76,790)(125,437)
Distributions to noncontrolling interest(11,273)(28,734)(43,673)(97,510)
Early retirement of debt— — (12,225)— 
Withholding tax on stock-based incentive awards153 — (7,094)(6,991)
Debt issuance, net of cost— — (613)— 
Repayment of term loan and other loans(371)(500,000)— — 
Capital lease obligation payments(178)(175)(514)(510)
Repurchase of common stock— (106,014)— (405,938)
Net cash (required) provided by financing activities(869)(2,074,857)59,091 (961,386)
Cash Flows from Discontinued Operations 1
Operating activities— (47,911)(1,202)74,361 
Investing activities— 2,035,000 4,494 1,985,202 
Financing activities— — — (4,914)
Net cash provided by discontinued operations— 1,987,089 3,292 2,054,649 
Cash transferred from discontinued operations to continuing operations— 2,035,000 — 2,083,565 
Effect of exchange rate changes on cash and cash equivalents773 (675)(585)2,593 
Net increase (decrease) in cash and cash equivalents74,131 108,855 (87,124)74,976 
Cash and cash equivalents at beginning of period145,505 326,044 306,760 359,923 
Cash and cash equivalents at end of period$219,636 434,899 219,636 434,899 
1 Net cash provided by discontinued operations is not part of the cash flow reconciliation.
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MURPHY OIL CORPORATION
SCHEDULE OF ADJUSTED INCOME (LOSS)
(unaudited)
Three Months Ended
September 30,
Nine Months Ended
September 30,
(Millions of dollars, except per share amounts)
2020201920202019
Net (loss) income attributable to Murphy (GAAP)$(243.6)1,089.0 (976.8)1,221.5 
Discontinued operations loss (income)
0.8 (953.4)6.9 (1,027.6)
(Loss) income from continuing operations(242.8)135.6 (969.9)193.9 
Adjustments (after tax):
Impairment of assets145.9 — 854.2 — 
Mark-to-market loss (gain) on crude oil derivative contracts54.8 (38.9)(82.5)(79.1)
Mark-to-market loss (gain) on contingent consideration
11.1 (22.4)(23.3)0.4 
Restructuring expenses3.9 — 35.5 — 
Unutilized rig charges4.1 — 10.4 — 
(Gain) loss on extinguishment of debt— — (4.2)— 
Inventory loss— — 3.8 — 
Foreign exchange losses (gains) 0.8 0.8 (1.7)5.9 
Business development transaction costs— 3.3 — 19.3 
Write-off of previously suspended exploration wells— — — 13.2 
Impact of tax reform— — — (13.0)
Tax benefits on investments in foreign areas— (15.0)— (15.0)
Seal insurance proceeds(1.3)(6.2)(1.3)(6.2)
Total adjustments after taxes219.3 (78.4)790.9 (74.5)
Adjusted (loss) income from continuing operations attributable to Murphy$(23.5)57.2 (179.0)119.4 
Adjusted (loss) income from continuing operations per average diluted share$(0.15)0.36 (1.17)0.71 
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
September 30, 2020
Nine Months Ended
September 30, 2020
(Millions of dollars)
Pretax
Tax
Net
Pretax
Tax
Net
Exploration & Production:
United States
$205.7 (44.6)161.1 1,021.3 (215.9)805.4 
Canada (1.7)0.4 (1.3)(1.7)0.4 (1.3)
Other International
— — — 39.7 — 39.7 
Total E&P
204.0 (44.2)159.8 1,059.3 (215.5)843.8 
Corporate:
75.3 (15.8)59.5 (65.8)12.9 (52.9)
Total adjustments
$279.3 (60.0)219.3 993.5 (202.6)790.9 
10


MURPHY OIL CORPORATION
SCHEDULE OF EARNINGS BEFORE INTEREST, TAXES, DEPRECIATION
AND AMORTIZATION (EBITDA)
(unaudited)

Three Months Ended
September 30,
Nine Months Ended
September 30,
(Millions of dollars, except per barrel of oil equivalents sold)
2020201920202019
Net (loss) income attributable to Murphy (GAAP)$(243.6)1,089.0 (976.8)1,221.5 
Income tax (benefit) expense(62.6)18.8 (248.9)38.7 
Interest expense, net45.2 44.9 124.9 145.1 
Depreciation, depletion and amortization expense ¹219.7 308.3 725.1 766.4 
EBITDA attributable to Murphy (Non-GAAP)(41.3)1,461.0 (375.7)2,171.7 
Impairment of assets ¹186.5 — 1,072.5 — 
Mark-to-market loss (gain) on crude oil derivative contracts69.3 (49.2)(104.5)(100.1)
Mark-to-market loss (gain) on contingent consideration14.0 (28.4)(29.5)0.5 
Restructuring expenses5.0 — 46.4 — 
Accretion of asset retirement obligations10.8 10.6 31.2 29.8 
Unutilized rig charges5.2 — 13.2 — 
Discontinued operations loss (income) 0.8 (953.4)6.9 (1,027.6)
Inventory loss— — 4.8 — 
Foreign exchange losses (gains) 0.8 0.8 (2.5)6.4 
Business development transaction costs— 4.1 — 24.4 
Write-off of previously suspended exploration wells— — — 13.2 
Seal insurance proceeds(1.7)(8.0)(1.7)(8.0)
Adjusted EBITDA attributable to Murphy (Non-GAAP)$249.4 437.5 661.1 1,110.3 
Total barrels of oil equivalents sold from continuing operations attributable to Murphy (thousands of barrels)14,166 17,745 46,478 45,511 
Adjusted EBITDA per barrel of oil equivalents sold$17.61 24.65 14.22 24.40 
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.

1 Depreciation, depletion, and amortization expense used in the computation of EBITDA and impairment of assets used in the computation of Adjusted EBITDA exclude the portion attributable to the non-controlling interest.
11


MURPHY OIL CORPORATION
SCHEDULE OF EARNINGS BEFORE INTEREST, TAXES, DEPRECIATION
AND AMORTIZATION AND EXPLORATION (EBITDAX)
(unaudited)

Three Months Ended
September 30,
Nine Months Ended
September 30,
(Millions of dollars, except per barrel of oil equivalents sold)
2020201920202019
Net (loss) income attributable to Murphy (GAAP)$(243.6)1,089.0 (976.8)1,221.5 
Income tax (benefit) expense(62.6)18.8 (248.9)38.7 
Interest expense, net45.2 44.9 124.9 145.1 
Depreciation, depletion and amortization expense ¹219.7 308.3 725.1 766.4 
EBITDA attributable to Murphy (Non-GAAP)(41.3)1,461.0 (375.7)2,171.7 
Exploration expenses12.1 12.4 61.7 75.6 
EBITDAX attributable to Murphy (Non-GAAP)(29.2)1,473.4 (314.0)2,247.3 
Impairment of assets ¹186.5 — 1,072.5 — 
Mark-to-market loss (gain) on crude oil derivative contracts69.3 (49.2)(104.5)(100.1)
Mark-to-market loss (gain) on contingent consideration14.0 (28.4)(29.5)0.5 
Restructuring expenses5.0 — 46.4 — 
Accretion of asset retirement obligations10.8 10.6 31.2 29.8 
Unutilized rig charges5.2 — 13.2 — 
Discontinued operations loss (income) 0.8 (953.4)6.9 (1,027.6)
Inventory loss— — 4.8 — 
Foreign exchange losses (gains) 0.8 0.8 (2.5)6.4 
Business development transaction costs— 4.1 — 24.4 
Seal insurance proceeds(1.7)(8.0)(1.7)(8.0)
Adjusted EBITDAX attributable to Murphy (Non-GAAP)$261.5 449.9 722.8 1,172.7 
Total barrels of oil equivalents sold from continuing operations attributable to Murphy (thousands of barrels)14,166 17,745 46,478 45,511 
Adjusted EBITDAX per barrel of oil equivalents sold$18.46 25.35 15.55 25.77 
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.
1 Depreciation, depletion, and amortization expense used in the computation of EBITDA and impairment of assets used in the computation of Adjusted EBITDA exclude the portion attributable to the non-controlling interest.
12


MURPHY OIL CORPORATION
FUNCTIONAL RESULTS OF OPERATIONS (unaudited)

Three Months Ended
September 30, 2020
Three Months Ended
September 30, 2019
(Millions of dollars)
RevenuesIncome
(Loss)
RevenuesIncome
(Loss)
Exploration and production
United States 1
$330.8 (172.6)656.8 170.8 
Canada96.3 (8.6)95.0 (9.1)
Other — (11.7)1.9 (3.7)
Total exploration and production427.1 (192.9)753.7 158.0 
Corporate(5.2)(72.9)63.4 0.3 
Revenue/income from continuing operations421.9 (265.8)817.1 158.3 
Discontinued operations, net of tax 3
— (0.8)— 953.4 
Total revenues/net income (loss) including noncontrolling interest$421.9 (266.6)817.1 1,111.7 
Net (loss) income attributable to Murphy(243.6)1,089.0 

Nine Months Ended
September 30, 2020
Nine Months Ended
September 30, 2019
(Millions of dollars)
RevenuesIncome
(Loss)
RevenuesIncome
(Loss)
Exploration and production
United States 1,2
$1,070.6 (1,011.7)1,734.3 420.0 
Canada245.2 (35.0)323.8 (7.5)
Other 2
1.8 (73.0)7.9 (35.4)
Total exploration and production1,317.6 (1,119.7)2,066.0 377.1 
Corporate319.5 26.9 125.6 (97.0)
Revenue/income from continuing operations1,637.1 (1,092.8)2,191.6 280.1 
Discontinued operations, net of tax 3
— (6.9)— 1,027.6 
Total revenues/net income (loss) including noncontrolling interest$1,637.1 (1,099.7)2,191.6 1,307.7 
Net income attributable to Murphy(976.8)1,221.5 
1 Includes results attributable to a noncontrolling interest in MP Gulf of Mexico, LLC (MP GOM).
2 Includes impairment charges of $1,152.5 million and $39.7 million for the United States and Other for the nine months ended September 30, 2020.
3 Malaysia is reported as discontinued operations in current and comparative periods effective January 1, 2019.
13


MURPHY OIL CORPORATION
OIL AND GAS OPERATING RESULTS (unaudited)
THREE MONTHS ENDED SEPTEMBER 30, 2020, AND 2019

(Millions of dollars)
United
States 1
Canada
Other
Total
Three Months Ended September 30, 2020
Oil and gas sales and other operating revenues$330.8 96.3 — 427.1 
Lease operating expenses91.5 32.6 0.4 124.5 
Severance and ad valorem taxes6.4 0.3 — 6.7 
Transportation, gathering and processing29.3 12.0 — 41.3 
Depreciation, depletion and amortization166.2 59.6 0.5 226.3 
Accretion of asset retirement obligations9.4 1.4 — 10.8 
Impairments of assets205.1 — — 205.1 
Exploration expenses
Dry holes and previously suspended exploration costs0.6 — — 0.6 
Geological and geophysical0.1 — (0.1)— 
Other exploration0.6 0.1 3.6 4.3 
1.3 0.1 3.5 4.9 
Undeveloped lease amortization4.9 0.1 2.3 7.3 
Total exploration expenses6.2 0.2 5.8 12.2 
Selling and general expenses5.3 3.4 1.6 10.3 
Other22.5 (1.5)2.5 23.5 
Results of operations before taxes(211.1)(11.7)(10.8)(233.6)
Income tax provisions (benefits)(38.5)(3.1)0.9 (40.7)
Results of operations (excluding Corporate segment)$(172.6)(8.6)(11.7)(192.9)
Three Months Ended September 30, 2019
Oil and gas sales and other operating revenues$656.8 95.0 1.9 753.7 
Lease operating expenses116.2 31.2 0.2 147.6 
Severance and ad valorem taxes13.4 0.4 — 13.8 
Transportation, gathering and processing44.1 10.2 — 54.3 
Depreciation, depletion and amortization253.5 65.3 0.6 319.4 
Accretion of asset retirement obligations9.0 1.6 — 10.6 
Exploration expenses
Dry holes and previously suspended exploration costs(0.1)— — (0.1)
Geological and geophysical0.2 — 0.2 0.4 
Other exploration1.5 0.1 3.8 5.4 
1.6 0.1 4.0 5.7 
Undeveloped lease amortization5.2 0.3 1.0 6.5 
Total exploration expenses6.8 0.4 5.0 12.2 
Selling and general expenses22.7 7.6 5.6 35.9 
Other(21.0)(7.3)0.5 (27.8)
Results of operations before taxes212.1 (14.4)(10.0)187.7 
Income tax provisions (benefits)41.3 (5.3)(6.3)29.7 
Results of operations (excluding Corporate segment)$170.8 (9.1)(3.7)158.0 
1 Includes results attributable to a noncontrolling interest in MP GOM.
14


MURPHY OIL CORPORATION
OIL AND GAS OPERATING RESULTS (unaudited)
NINE MONTHS ENDED SEPTEMBER 30, 2020, AND 2019

(Millions of dollars)
United
States 1
Canada
Other
Total
Nine Months Ended September 30, 2020
Oil and gas sales and other operating revenues$1,070.6 245.2 1.8 1,317.6 
Lease operating expenses386.5 90.6 1.2 478.3 
Severance and ad valorem taxes21.6 1.0 — 22.6 
Transportation, gathering and processing95.4 31.4 — 126.8 
Depreciation, depletion and amortization589.5 161.3 1.5 752.3 
Accretion of asset retirement obligations27.1 4.1 — 31.2 
Impairment of assets1,152.5 — 39.7 1,192.2 
Exploration expenses
Dry holes and previously suspended exploration costs8.3 — — 8.3 
Geological and geophysical9.4 0.1 4.1 13.6 
Other exploration4.3 0.4 13.1 17.8 
22.0 0.5 17.2 39.7 
Undeveloped lease amortization14.8 0.3 6.9 22.0 
Total exploration expenses36.8 0.8 24.1 61.7 
Selling and general expenses16.6 13.2 5.5 35.3 
Other1.0 (2.5)1.4 (0.1)
Results of operations before taxes(1,256.4)(54.7)(71.6)(1,382.7)
Income tax provisions (benefits)(244.7)(19.7)1.4 (263.0)
Results of operations (excluding Corporate segment)$(1,011.7)(35.0)(73.0)(1,119.7)
Nine Months Ended September 30, 2019
Oil and gas sales and other operating revenues$1,734.3 323.8 7.9 2,066.0 
Lease operating expenses308.3 107.1 1.1 416.5 
Severance and ad valorem taxes36.0 1.0 — 37.0 
Transportation, gathering and processing103.4 25.3 — 128.7 
Depreciation, depletion and amortization618.6 181.6 2.9 803.1 
Accretion of asset retirement obligations25.2 4.6 — 29.8 
Exploration expenses
Dry holes and previously suspended exploration costs(0.2)— 13.1 12.9 
Geological and geophysical16.1 — 8.1 24.2 
Other exploration5.5 0.3 10.9 16.7 
21.4 0.3 32.1 53.8 
Undeveloped lease amortization18.0 1.0 2.7 21.7 
Total exploration expenses39.4 1.3 34.8 75.5 
Selling and general expenses52.9 21.3 17.3 91.5 
Other37.5 (6.9)0.9 31.5 
Results of operations before taxes513.0 (11.5)(49.1)452.4 
Income tax provisions (benefits)93.0 (4.0)(13.7)75.3 
Results of operations (excluding Corporate segment)$420.0 (7.5)(35.4)377.1 
1 Includes results attributable to a noncontrolling interest in MP GOM.
15


MURPHY OIL CORPORATION
PRODUCTION-RELATED EXPENSES
(unaudited)

Three Months Ended
September 30,
Nine Months Ended
September 30,
(Dollars per barrel of oil equivalents sold)
2020201920202019
Continuing operations
United States – Eagle Ford Shale
Lease operating expense
$8.11 6.74 8.97 8.92 
Severance and ad valorem taxes
2.04 2.87 2.08 3.01 
Depreciation, depletion and amortization (DD&A) expense
27.09 24.29 25.72 23.94 
United States – Gulf of Mexico
Lease operating expense 1
$10.16 10.20 12.60 9.70 
DD&A expense
12.33 16.86 13.82 16.01 
Canada – Onshore
Lease operating expense
$4.73 4.36 4.56 5.40 
Severance and ad valorem taxes
0.05 0.07 0.07 0.07 
DD&A expense
10.78 11.26 9.94 11.07 
Canada – Offshore
Lease operating expense
$20.30 17.43 16.71 16.91 
DD&A expense
12.58 11.55 11.48 13.36 
Total oil and gas continuing operations
Lease operating expense 2
$8.23 7.85 9.61 8.52 
Severance and ad valorem taxes
0.45 0.73 0.45 0.76 
DD&A expense
15.31 17.31 15.45 16.75 
Total oil and gas continuing operations – excluding noncontrolling interest
Lease operating expense
$8.13 7.68 9.36 8.45 
Severance and ad valorem taxes
0.48 0.73 0.49 0.76 
DD&A expense
15.51 17.03 15.60 16.84 
1 For the nine months ended September 30, 2020, lease operating expense (LOE) per barrel of oil equivalents (BOE) sold for the U.S. Gulf of Mexico excluding cost associated with well workovers is $9.49. Workovers for the nine months ended September 30, 2020 include Dalmatian and Cascade. There were no significant Gulf of Mexico workovers in the third quarter 2020.
2 For the nine months ended September 30, 2020, total LOE per BOE excluding cost associated with Gulf of Mexico well workovers is $7.86. There were no significant Gulf of Mexico workovers in the third quarter 2020.



16


MURPHY OIL CORPORATION
OTHER FINANCIAL DATA
(unaudited)

Three Months Ended
September 30,
Nine Months Ended
September 30,
(Millions of dollars)
2020201920202019
Capital expenditures for continuing operations
Exploration and production
United States $116.6 295.5 521.7 2,042.3 
Canada(1.6)45.9 116.6 201.6 
Other5.8 12.3 32.7 76.7 
Total120.8 353.7 671.0 2,320.6 
Corporate1.9 2.9 9.3 8.5 
Total capital expenditures - continuing operations 1
122.7 356.6 680.3 2,329.1 
Charged to exploration expenses 2
United States1.3 1.6 22.0 21.4 
Canada0.1 0.1 0.5 0.3 
Other3.5 4.0 17.2 32.1 
Total charged to exploration expenses - continuing operations4.9 5.7 39.7 53.8 
Total capitalized $117.8 350.9 640.6 2,275.3 
1 For the three and nine months ended September 30, 2020, includes noncontrolling interest (NCI) capital expenditures of $2.3 million and $17.8 million, respectively. For the three and nine months ended September 30, 2020, includes capital expenditures associated with the King’s Quay project of $19.3 million and $80.7 million.
2 Excludes amortization of undeveloped leases of $7.3 million and $6.5 million for the three months ended September 30, 2020 and 2019, respectively. Excludes amortization of undeveloped leases of $22.0 million and $21.7 million for the nine months ended September 30, 2020 and 2019, respectively.

17


MURPHY OIL CORPORATION
CONSOLIDATED BALANCE SHEETS
(unaudited)

(Millions of dollars)September 30,
2020
December 31,
2019
ASSETS
Current assets
Cash and cash equivalents$219.6 306.8 
Accounts receivable279.1 426.7 
Inventories67.9 76.1 
Prepaid expenses58.1 40.9 
Assets held for sale108.9 123.9 
Total current assets733.7 974.3 
Property, plant and equipment, at cost
8,592.8 9,969.7 
Operating lease assets765.5 598.3 
Deferred income taxes347.1 129.3 
Deferred charges and other assets30.3 46.9 
Total assets$10,469.4 11,718.5 
LIABILITIES AND EQUITY
Current liabilities
Accounts payable$295.4 602.1 
Income taxes payable17.8 19.0 
Other taxes payable23.8 18.6 
Operating lease liabilities100.2 92.3 
Other accrued liabilities157.6 197.4 
Liabilities associated with assets held for sale14.7 13.3 
Total current liabilities609.4 942.8 
Long-term debt, including capital lease obligation2,987.1 2,803.4 
Asset retirement obligations856.9 825.8 
Deferred credits and other liabilities636.0 613.4 
Non-current operating lease liabilities686.5 521.3 
Deferred income taxes179.5 207.2 
Total liabilities5,955.3 5,913.9 
Equity
Common Stock, par $1.00
195.1 195.1 
Capital in excess of par value936.3 949.4 
Retained earnings5,560.7 6,614.3 
Accumulated other comprehensive loss(658.0)(574.2)
Treasury stock(1,690.7)(1,717.2)
Murphy Shareholders' Equity4,343.4 5,467.5 
Noncontrolling interest170.6 337.2 
Total equity4,514.0 5,804.6 
Total liabilities and equity$10,469.4 11,718.5 

18


MURPHY OIL CORPORATION
PRODUCTION SUMMARY
(unaudited)
Three Months Ended
September 30,
Nine Months Ended
September 30,
Barrels per day unless otherwise noted2020201920202019
Continuing operations
Net crude oil and condensate
United StatesOnshore24,851 40,582 27,945 33,256 
Gulf of Mexico 1
56,517 70,583 67,377 64,266 
CanadaOnshore9,595 7,101 8,106 6,503 
Offshore4,428 4,333 5,136 6,302 
Other— 351 114 435 
Total net crude oil and condensate - continuing operations95,391 122,950 108,678 110,762 
Net natural gas liquids
United StatesOnshore5,489 5,582 5,459 5,621 
Gulf of Mexico 1
3,521 6,597 5,131 4,172 
CanadaOnshore1,513 1,422 1,311 1,197 
Total net natural gas liquids - continuing operations10,523 13,601 11,901 10,990 
Net natural gas – thousands of cubic feet per day
United StatesOnshore27,520 29,122 29,054 30,203 
Gulf of Mexico 1
53,046 72,897 67,850 44,029 
CanadaOnshore260,895 296,883 262,279 267,205 
Total net natural gas - continuing operations341,461 398,902 359,183 341,437 
Total net hydrocarbons - continuing operations including NCI 2,3
162,824 203,035 180,443 178,658 
Noncontrolling interest
Net crude oil and condensate – barrels per day(9,298)(10,322)(10,674)(11,215)
Net natural gas liquids – barrels per day(327)(478)(443)(496)
Net natural gas – thousands of cubic feet per day 2
(3,269)(3,403)(4,137)(3,933)
Total noncontrolling interest(10,170)(11,367)(11,807)(12,367)
Total net hydrocarbons - continuing operations excluding NCI 2,3
152,654 191,668 168,636 166,292 
Discontinued operations
Net crude oil and condensate – barrels per day— 1,748 — 16,331 
Net natural gas liquids – barrels per day— 37 — 434 
Net natural gas – thousands of cubic feet per day 2
— 9,624 — 67,863 
Total discontinued operations— 3,389 — 28,076 
Total net hydrocarbons produced excluding NCI 2,3
152,654 195,057 168,636 194,367 
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.
19


MURPHY OIL CORPORATION
PRICE SUMMARY
(unaudited)
Three Months Ended
September 30,
Nine Months Ended
September 30,
2020201920202019
Weighted average Exploration and Production sales prices 1
Continuing operations
Crude oil and condensate – dollars per barrel
United StatesOnshore$37.83 58.80 35.56 60.33 
Gulf of Mexico 2
40.82 60.69 38.08 61.90 
Canada 3
Onshore36.65 48.61 30.29 49.98 
Offshore43.81 62.44 37.85 64.97 
Other— 67.96 63.51 69.86 
Natural gas liquids – dollars per barrel
United StatesOnshore13.39 10.82 10.78 14.66 
Gulf of Mexico 2
14.71 13.86 9.43 15.96 
Canada 3
Onshore19.97 21.03 16.95 27.50 
Natural gas – dollars per thousand cubic feet
United StatesOnshore1.78 2.18 1.76 2.51 
Gulf of Mexico 2
2.01 2.37 1.91 2.46 
Canada 3
Onshore1.74 1.16 1.62 1.50 
1 Effective September 30, 2019, weighted average realized prices are reported excluding transportation, gathering and processing costs.
2 Prices include the effect of noncontrolling interest share for MP GOM.
3 U.S. dollar equivalent.


20


MURPHY OIL CORPORATION
COMMODITY HEDGE POSITIONS (unaudited)
AS OF NOVEMBER 4, 2020
CommodityTypeVolumes
(Bbl/d)
Price
(USD/Bbl)
Remaining Period
AreaStart DateEnd Date
United StatesWTI ¹Fixed price derivative swap45,000 $56.42 10/1/202012/31/2020
United StatesWTI ¹Fixed price derivative swap18,000 $43.31 1/1/202112/31/2021
1 West Texas Intermediate
Volumes
(MMcf/d)
Price
(CAD/Mcf)
Remaining Period
AreaCommodityTypeStart DateEnd Date
MontneyNatural GasFixed price forward sales at AECO59 C$2.8110/1/202012/31/2020
MontneyNatural GasFixed price forward sales at AECO96 C$2.531/1/202112/31/2021
MontneyNatural GasFixed price forward sales at AECO71 C$2.501/1/202212/31/2024
Volumes
(MMcf/d)
Price
(USD/MMBtu)
Remaining Period
AreaCommodityTypeStart DateEnd Date
MontneyNatural GasFixed price forward sales at Malin20 $2.60 1/1/202112/31/2022
21


MURPHY OIL CORPORATION
FOURTH QUARTER 2020 GUIDANCE
Oil
BOPD
NGLs
BOPD
Gas
MCFD
Total
BOEPD
Production – net
U.S.  – Eagle Ford Shale21,200 4,600 25,000 30,000 
– Gulf of Mexico excluding NCI 50,900 5,300 61,000 66,400 
Canada – Tupper Montney— — 225,000 37,500 
– Kaybob Duvernay and Placid Montney
7,000 1,400 22,400 12,100 
– Offshore
4,000 — — 4,000 
Total net production (BOEPD) - excluding NCI 1
146,000 to 154,000
Exploration expense ($ millions)$25
FULL YEAR 2020 GUIDANCE
Capital expenditures – excluding NCI ($ millions) 2
$680 to $720
1 Excludes noncontrolling interest of MP GOM of 8,300 BOPD of oil, 500 BOPD of NGLs, and 3,800 MCFD gas.
2 Excludes noncontrolling interest of MP GOM of $41 MM.

22