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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): January 28, 2021
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 January 28, 2021 Murphy Oil Corporation issued a news release announcing its financial and operating results for the quarter and year ended December 31, 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: January 28, 2021
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 FOURTH QUARTER
AND FULL YEAR 2020 RESULTS,
PROVIDES 2021 CAPITAL EXPENDITURE AND PRODUCTION GUIDANCE

Sanctioned Low Cost Tupper Montney Natural Gas Development

HOUSTON, Texas, January 28, 2021 - Murphy Oil Corporation (NYSE: MUR) today announced its financial and operating results for the fourth quarter ended December 31, 2020, including a net loss attributable to Murphy of $172 million, or $1.11 net loss per diluted share. Adjusted net loss, which excludes discontinued operations and other one-off items, was $14 million, or $0.09 net loss per diluted share.
Unless otherwise noted, the financial and operating highlights and metrics discussed in this commentary exclude noncontrolling interest. 1
Highlights for the fourth quarter include:
•Sanctioned low cost, capital efficient Tupper Montney development
•Produced 149 thousand barrels of oil equivalent per day, in line with guidance
•Generated adjusted EBITDAX of $271 million, or $19.77 per barrel of oil equivalent sold
•Continued on-time and on-budget execution of major Gulf of Mexico projects
Highlights for full year 2020 include:
•Preserved liquidity of $1.7 billion, including $311 million of cash at year-end
•Maintained capital discipline with full year accrued capital expenditures of $712 million, excluding King’s Quay floating production system
•Decreased full year G&A costs by 40 percent from 2019, establishing a baseline for a continued lower cost structure
•Established a greenhouse gas emissions intensity reduction goal of 15 to 20 percent by 2030 from 2019 levels, excluding Malaysia
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•Instituted COVID-19 protocols, resulting in an offshore infection rate at half the industry average while maintaining all project timelines
•Maintained a reserve life index of more than 11 years with 57 percent proved developed reserves
During and subsequent to the fourth quarter:
•Entered into additional crude oil hedges for 2021 and 2022, bringing the total contracted position to 45 thousand barrels of oil per day and 20 thousand barrels of oil per day, respectively
•Committed to fixed price forward sales contracts related to the Tupper Montney asset for calendar years 2021 through 2024
“We quickly responded to the major pullback in commodity prices by drastically reducing our capital budget and cost structure while adjusting our operational plans, and continued supporting capital allocation to our major offshore projects. Our efforts resulted in strong liquidity, cash on hand and paying a dividend to our shareholders,” stated Roger W. Jenkins, President and Chief Executive Officer.
FOURTH QUARTER 2020 RESULTS
The company recorded a net loss, attributable to Murphy, of $172 million, or $1.11 net loss per diluted share, for the fourth 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 $14 million, or $0.09 net loss per diluted share for the same period. The adjusted net loss from continuing operations excludes the following primary after-tax items: $137 million mark-to-market loss on crude oil derivative contracts and $12 million mark-to-market loss on contingent consideration. Details for fourth 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 $246 million, or $17.96 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 $271
2

million, or $19.77 per BOE sold. Details for fourth quarter EBITDA and EBITDAX reconciliations can be found in the attached schedules.
Fourth quarter production averaged 149 thousand barrels of oil equivalent per day (MBOEPD) with 55 percent oil and 62 percent liquids. Production was impacted by two subsea equipment issues in the Gulf of Mexico late in the quarter, totaling approximately 3,700 BOEPD of unplanned downtime. The subsea repairs are ongoing, with a return to full production expected during the first quarter 2021. Our onshore assets were able to offset the impact of the subsea matters due to strong well performance.
Details for fourth quarter production can be found in the attached schedules.
FULL YEAR 2020 RESULTS
The company recorded a net loss, attributable to Murphy, of $1.1 billion, or $7.48 net loss per diluted share, for the full year 2020. The company reported an adjusted loss, which excludes both the results of discontinued operations and certain other items that affect comparability of results between periods, of $193 million, or $1.25 net loss per diluted share. This includes after tax impairments of $854 million. Details for full year 2020 results can be found in the attached schedules.
Production for the full year averaged 164 MBOEPD and consisted of 57 percent oil and 64 percent liquids volumes. Details for 2020 production can be found in the attached tables.
FINANCIAL POSITION
The company had $2.8 billion of outstanding long-term, fixed-rate notes at the end of fourth quarter 2020. The fixed-rate notes had a weighted average maturity of 6.8 years and a weighted average coupon of 5.9 percent. Murphy also had $200 million drawn on the $1.6 billion senior unsecured credit facility at year-end 2020.
As of December 31, 2020, Murphy had approximately $1.7 billion of liquidity, comprised of $1.4 billion available under the $1.6 billion senior unsecured credit facility and approximately $311 million of cash and cash equivalents.
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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 and subsequent to the fourth quarter, Murphy layered on hedges to protect cash flow with the execution of West Texas Intermediate (WTI) fixed price swaps, as detailed in the table below.
Type
Volumes (MBOPD)
Price (BBL)
Start Date
End Date
WTI Fixed Price Swaps45$42.771/1/202112/31/2021
WTI Fixed Price Swaps20$44.881/1/202212/31/2022
As of January 26, 2021
To support the sanctioned Tupper Montney development, the company also entered into fixed price forward sales contracts for physical delivery at the AECO hub in Canada, with the current contracts as follows:
Type
Volumes (MMCFD)
Price (MCF)
Start Date
End Date
Fixed Price Forward Sales at AECO
160
C$2.54
1/1/2021
1/31/2021
Fixed Price Forward Sales at AECO
203
C$2.55
2/1/2021
5/31/2021
Fixed Price Forward Sales at AECO
212
C$2.55
6/1/2021
12/31/2021
Fixed Price Forward Sales at AECO
222
C$2.41
1/1/2022
12/31/2022
Fixed Price Forward Sales at AECO
192
C$2.36
1/1/2023
12/31/2023
Fixed Price Forward Sales at AECO
147
C$2.41
1/1/2024
12/31/2024
As of January 26, 2021
YEAR-END 2020 PROVED RESERVES
Murphy’s preliminary year-end 2020 proved reserves were 697 million barrels of oil equivalent (MMBOE), consisting of 36 percent oil and 41 percent liquids. Total proved reserves were 13 percent lower than at year-end 2019 in part due to a nearly 30 percent reduction in crude oil prices. Additionally, Murphy’s focus on free cash flow generation, resulting in a lower capital allocation and flatter oil shale production over the five-year plan, has led to approximately 149 MMBOE net of Eagle Ford Shale and Kaybob Duvernay proved undeveloped reserves being reclassified as probable reserves.
4

These proved reserve reductions were partially offset by improved well performance in the Gulf of Mexico totaling 13 MMBOE net, as well as sanctioning the Tupper Montney development, which added more than 750 billion cubic feet equivalent (BCFE), or 126 MMBOE, of proved reserves with low subsurface risk.
The company maintained a reserve life index in excess of 11 years with 57 percent proved developed reserves.
2020 Proved Reserves – Preliminary *
Category
Net Oil
(MMBBL)
Net NGLs
(MMBBL)
Net Gas (BCF)
Net Equiv. (MMBOE)
Proved Developed (PD)
167
28
1,208
397
Proved Undeveloped (PUD)
84
9
1,246
301
Total Proved
251
38
2,454
697
* Reserves are based on preliminary year-end 2020 audited proved reserves. Numbers may not add exactly due to rounding.
“We are pleased with the improved well performance in our Gulf of Mexico wells. Further, by sanctioning the low-cost Tupper Montney development, we were able to add more than 750 BCFE of, natural gas reserves with minimal subsurface risk to our proved reserve base,” stated Jenkins. “Outside of the current five-year plan, we do plan to continue developing the Eagle Ford Shale and Kaybob Duvernay, which would lead to the probable reserves being reclassified as proved undeveloped reserves.”
REGIONAL OPERATIONS SUMMARY
North American Onshore
The North American onshore business produced approximately 82 MBOEPD in the fourth quarter.
Eagle Ford Shale – During the quarter, production averaged 31 MBOEPD with 71 percent oil volumes.
Tupper Montney – Natural gas production averaged 234 million cubic feet per day (MMCFPD) for the quarter.
Kaybob Duvernay – Fourth quarter production averaged 10 MBOEPD.
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Global Offshore
The offshore business produced 67 MBOEPD for the fourth quarter, comprised of 79 percent oil. This excludes production from discontinued operations and noncontrolling interest. Gulf of Mexico production in the quarter averaged 63 MBOEPD, consisting of 78 percent oil. Canada offshore production averaged 4 MBOEPD, comprised of 100 percent oil.
Gulf of Mexico – The company progressed the Calliope subsea work during the quarter and remains on schedule for second quarter 2021 production. The Khaleesi, Mormont and Samurai project advanced ahead of the 2021 drilling campaign, with first oil remaining on target for mid-2022. Construction of the King’s Quay floating production system continued and is approximately 90 percent complete, having reached a significant milestone of mating the hull and topsides.
Murphy, along with its operating partner, drilled a producer well and injector well for the St. Malo waterflood during the quarter. The company also worked with a separate operating partner to spud the Lucius #9 and Lucius #3 wells in Keathley Canyon. Completions work was initiated on the non-operated Kodiak #3 well, which is scheduled to come online in first quarter 2021.
EXPLORATION
Gulf of Mexico – The non-operated Highgarden well (Green Canyon 895) reached total depth in the fourth quarter and has been classified as a dry hole. The 20 percent working interest resulted in a final cost of $12.8 million net to Murphy.
Also in the fourth quarter, Murphy successfully bid on eight blocks in the deepwater Gulf of Mexico lease sale with a net cost of $5.3 million for 100 percent working interest. These blocks include five prospects and provide standalone and near-field opportunities with an average gross resource potential of more than 90 MMBOE. Subsequent to quarter end, these blocks were awarded to Murphy by the Bureau of Energy Management.
Murphy has farmed into an attractive play-opening trend with Chevron as operator, and the first well is planned for the Silverback prospect (Mississippi Canyon 35). The acreage is located adjacent to a large position held by Murphy and its partners.
6

2021 CAPITAL EXPENDITURE AND PRODUCTION GUIDANCE
Murphy is planning 2021 capital expenditures (CAPEX) to be in the range of $675 to $725 million with full year 2021 production to be in the range of 155 to 165 MBOEPD, comprised of approximately 52 percent oil and 59 percent total liquids volumes. Production for first quarter 2021 is estimated to be in the range of 149 to 157 MBOEPD. Both production and CAPEX guidance ranges exclude Gulf of Mexico noncontrolling interest (NCI). Murphy’s 2021 plan reflects management’s continued focus on spending within cash flow, with capital directed toward major projects and short-term free cash flow-generating projects. Such a plan would allow the company to return cash to shareholders through the longstanding dividend, with additional cash utilized in a price recovery to pay down debt.
The table below illustrates the capital allocation by area.
2021 Capital Expenditure Guidance
Area
Percent of Total CAPEX
Gulf of Mexico
46
US Onshore
24
Canada Onshore
14
Exploration
11
Canada Offshore
1
Other
4
For 2021, Murphy has allocated approximately $325 million, or 46 percent, of capital to the Gulf of Mexico for both development drilling and field development projects. These projects include activities related to the previously sanctioned Khaleesi / Mormont and Samurai developments, and the St. Malo waterflood project. The non-operated Kodiak #3 well (Mississippi Canyon 727), Lucius #9 well (Keathley Canyon 919), Lucius #3 well (Keathley Canyon 918) are scheduled to be complete and placed online in the first half of 2021.
Canada offshore spending comprises 1 percent of the budget, with approximately $5 million earmarked to support Hibernia.
The company forecasts total 2021 offshore production volumes to average 72 MBOEPD, with Gulf of Mexico production of 68 MBOEPD. Canada offshore production is forecast at 4 MBOEPD, noting that non-operated Terra Nova continues to remain offline for repairs.
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Murphy plans to spend $170 million in the Eagle Ford Shale, which is 17 percent lower than in 2020. This capital includes $115 million for drilling and bringing online 19 operated wells in the company’s Karnes and Catarina acreage, as well as drilling 2 and bringing online 53 non-operated wells during the year, primarily in Karnes. Murphy’s Eagle Ford Shale budget also includes $55 million for field development.
The company has also allocated $95 million to its Canada onshore business in the Kaybob Duvernay, Tupper Montney and Placid Montney. Approximately $85 million is allocated to the newly sanctioned Tupper Montney to drill 10 operated wells and bring online 14 operated wells. The remaining amount is primarily allocated to Kaybob Duvernay for field development.
2021 Onshore Wells Online
1Q 2021
2Q 2021
3Q 2021
4Q 2021
2021 Total
Eagle Ford Shale
16
3
-
-
19
Kaybob Duvernay
-
-
-
-
-
Tupper Montney
4
5
5
-
14
Non-Op Eagle Ford Shale
-
20
33
-
53
Non-Op Placid Montney
-
-
-
-
-
Note: All well counts are shown gross. Eagle Ford Shale non-operated working interest averages 18 percent.
North American onshore production for 2021 is forecast to remain flat at approximately 87 MBOEPD. Annual average production in the Eagle Ford Shale is expected at approximately 30 MBOEPD, while the Kaybob Duvernay is planned to produce 7 MBOEPD. Non-operated Placid Montney production is projected to remain flat at nearly 2 MBOEPD. Tupper Montney production is forecast to increase to approximately 288 MMCFD (48 MBOEPD).
Approximately $75 million is allocated to the 2021 exploration program in the Gulf of Mexico, offshore Mexico and Brazil, with the majority of spending allocated to drilling. Other capital of approximately $30 million, or 4 percent of budget, primarily consists of capitalized interest.
Detailed guidance for the first quarter and full year 2021 is contained in the following schedule.
“Our major Gulf of Mexico projects continue to move forward, with the drilling campaign for Khaleesi, Mormont and Samurai launching early this year, along with drilling meaningful exploration wells in Brazil and Gulf of Mexico,” stated Jenkins. “Further, I am pleased with sanctioning the low cost, capital efficient Tupper Montney development. Over the past few
8

years, we have seen great improvement in all facets of these operations, including reductions in operating expenses and drilling and completions costs, as well as stronger base production performance. When coupled with the macro improvements of higher Canadian natural gas prices and production debottlenecking in the area, the Tupper Montney now competes with premiere shale assets in North America.”
CONFERENCE CALL AND WEBCAST SCHEDULED FOR JANUARY 28, 2021
Murphy will host a conference call to discuss fourth quarter 2020 financial and operating results on Thursday, January 28, 2021, 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 95330576.
FINANCIAL DATA
Summary financial data and operating statistics for fourth 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 first 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
9

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.
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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.
RESERVE REPORTING TO THE SECURITIES EXCHANGE COMMISSION
The SEC requires oil and natural gas companies, in their filings with the SEC, to disclose proved reserves that a company has demonstrated by actual production or conclusive formation tests to be economically and legally producible under existing economic and operating conditions. We may use certain terms in this news release, such as “resource”, “gross resource”, “recoverable resource”, “net risked PMEAN resource”, “recoverable oil”, “resource base”, “EUR” or “estimated ultimate recovery” and similar terms that the SEC’s rules prohibit us from including in filings with the SEC. The SEC permits the optional disclosure of probable and possible reserves; however, we have not disclosed the company’s probable and possible reserves in our filings with the SEC. Investors are urged to consider closely the disclosures and risk factors in our most recent Annual Report on Form 10-K filed with the 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.
Investor Contacts:
Kelly Whitley, kelly_whitley@murphyoilcorp.com, 281-675-9107
Megan Larson, megan_larson@murphyoilcorp.com, 281-675-9470
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MURPHY OIL CORPORATION
SUMMARIZED CONSOLIDATED STATEMENTS OF OPERATIONS (unaudited)
Three Months Ended
December 31,		Year Ended
December 31,
(Thousands of dollars, except per share amounts)
20202019 20202019
Revenues and other income
Revenue from sales to customers$440,082 756,984 1,751,709 2,817,111 
(Loss) gain on crude contracts(116,841)(122,019)202,661 (856)
Gain on sale of assets and other income6,965 2,515 12,971 12,798 
Total revenues and other income330,206 637,480 1,967,341 2,829,053 
Costs and expenses
Lease operating expenses121,793 188,720 600,076 605,180 
Severance and ad valorem taxes5,881 10,987 28,526 47,959 
Transportation, gathering and processing 45,620 47,567 172,399 176,315 
Exploration expenses, including undeveloped lease amortization24,793 19,535 86,479 95,105 
Selling and general expenses35,862 56,478 140,243 232,736 
Restructuring expenses3,615 — 49,994 — 
Depreciation, depletion and amortization218,088 328,572 987,239 1,147,842 
Accretion of asset retirement obligations10,923 10,682 42,136 40,506 
Impairment of assets— — 1,206,284 — 
Other (benefit) expense19,231 11,675 16,274 38,117 
Total costs and expenses485,806 674,216 3,329,650 2,383,760 
Operating (loss) income from continuing operations(155,600)(36,736)(1,362,309)445,293 
Other income (loss)
Interest and other income (loss)(7,196)(4,386)(17,303)(22,520)
Interest expense, net(44,546)(74,180)(169,423)(219,275)
Total other loss(51,742)(78,566)(186,726)(241,795)
(Loss) income from continuing operations before income taxes(207,342)(115,302)(1,549,035)203,498 
Income tax (benefit) expense (44,851)(24,036)(293,741)14,683 
(Loss) income from continuing operations(162,491)(91,266)(1,255,294)188,815 
(Loss) income from discontinued operations, net of income taxes(244)36,855 (7,151)1,064,487 
Net (loss) income including noncontrolling interest(162,735)(54,411)(1,262,445)1,253,302 
Less: Net (loss) income attributable to noncontrolling interest9,201 17,313 (113,668)103,570 
NET (LOSS) INCOME ATTRIBUTABLE TO MURPHY$(171,936)(71,724)(1,148,777)1,149,732 
(LOSS) INCOME PER COMMON SHARE – BASIC
Continuing operations$(1.11)(0.71)(7.43)0.52 
Discontinued operations— 0.24 (0.05)6.49 
Net (loss) income $(1.11)(0.47)(7.48)7.01 
(LOSS) INCOME PER COMMON SHARE – DILUTED
Continuing operations$(1.11)(0.70)(7.43)0.52 
Discontinued operations— 0.24 (0.05)6.46 
Net (loss) income $(1.11)(0.46)(7.48)6.98 
Cash dividends per Common share0.125 0.25 0.625 1.00 
Average Common shares outstanding (thousands)
Basic153,599 154,007 153,507 163,992 
Diluted153,599 154,915 153,507 164,812 

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MURPHY OIL CORPORATION
CONSOLIDATED STATEMENTS OF CASH FLOWS (unaudited)
Three Months Ended
December 31,		Year Ended
December 31,
(Thousands of dollars)
20202019 20202019
Operating Activities
Net (loss) income including noncontrolling interest$(162,735)(54,411)(1,262,445)1,253,302 
Adjustments to reconcile net (loss) income to net cash (required) provided by continuing operations activities:
Loss (income) from discontinued operations244 (36,855)7,151 (1,064,487)
Depreciation, depletion and amortization218,088 328,572 987,239 1,147,842 
Previously suspended exploration costs 12,844 (61)21,099 12,840 
Amortization of undeveloped leases4,792 6,293 26,743 27,973 
Accretion of asset retirement obligations10,923 10,682 42,136 40,506 
Impairment of assets— — 1,206,284 — 
Deferred income tax (benefit) expense(46,294)(22,067)(278,042)28,530 
Mark to market (gain) loss on contingent consideration15,693 8,160 (13,783)8,672 
Mark to market (gain) loss of crude contracts
173,773 133,440 69,310 33,364 
Noncash restructuring expense— — 17,565 — 
Long-term non-cash compensation11,358 16,391 46,558 76,958 
Net decrease (increase) in noncash operating working capital(5,766)(57,144)(32,027)(16,887)
Other operating activities, net(8,243)2,878 (35,080)(59,508)
Net cash provided by continuing operations activities224,677 335,878 802,708 1,489,105 
Investing Activities
Property additions and dry hole costs(111,084)(248,560)(759,809)(1,244,069)
Property additions for King's Quay FPS(38,025)(86,565)(112,961)(100,202)
Acquisition of oil and gas properties— 634 — (1,212,315)
Proceeds from sales of property, plant and equipment13,750 1,310 13,750 20,382 
Net cash required by investing activities(135,359)(333,181)(859,020)(2,536,204)
Financing Activities
Borrowings on revolving credit facility — 150,000 450,000 1,725,000 
Repayment of revolving credit facility — (150,000)(250,000)(2,050,000)
Cash dividends paid(19,199)(38,232)(95,989)(163,669)
Distributions to noncontrolling interest— (30,648)(43,673)(128,158)
Early retirement of debt— (521,332)(12,225)(521,332)
Withholding tax on stock-based incentive awards— — (7,094)(6,991)
Debt issuance, net of cost— 542,394 (613)542,394 
Capital lease obligation payments(181)(178)(695)(688)
Loss on early extinguishment of debt— (26,626)— (26,626)
Repurchase of common stock— (93,986)— (499,924)
Net cash (required) provided by financing activities(19,380)(168,608)39,711 (1,129,994)
Cash Flows from Discontinued Operations 1
Operating activities— (578)(1,202)73,783 
Investing activities— 36,832 4,494 2,022,034 
Financing activities— — — (4,914)
Net cash provided by discontinued operations— 36,254 3,292 2,090,903 
Cash from discontinued operations 18,438 36,832 18,438 2,120,397 
Effect of exchange rate changes on cash and cash equivalents2,594 940 2,009 3,533 
Net increase (decrease) in cash and cash equivalents90,970 (128,139)3,846 (53,163)
Cash and cash equivalents at beginning of period219,636 434,899 306,760 359,923 
Cash and cash equivalents at end of period$310,606 306,760 310,606 306,760 
1 Net cash provided by discontinued operations is not part of the cash flow reconciliation.
13

MURPHY OIL CORPORATION
SCHEDULE OF ADJUSTED INCOME (LOSS) (unaudited)
Three Months Ended
December 31,		Year Ended
December 31,
(Millions of dollars, except per share amounts)
2020201920202019
Net (loss) income attributable to Murphy (GAAP)$(171.9)(71.7)(1,148.8)1,149.7 
Discontinued operations loss (income)
0.2 (36.9)7.2 (1,064.5)
(Loss) income from continuing operations(171.7)(108.6)(1,141.6)85.2 
Adjustments (after tax):
Impairment of assets— — 854.2 — 
Mark-to-market (gain) loss on crude oil derivative contracts137.3 105.5 54.8 26.4 
Restructuring expenses2.8 — 38.3 — 
Unutilized rig charges2.3 — 12.7 — 
Mark-to-market (gain) loss on contingent consideration
12.4 6.5 (10.9)6.9 
Inventory loss2.8 — 6.6 — 
(Gain) loss on extinguishment of debt— 25.4 (4.2)25.4 
Retirement obligation (gains) losses(2.2)— (2.2)— 
Seal insurance proceeds— — (1.3)(6.2)
Foreign exchange (gains) losses 2.8 — 1.1 5.9 
Business development transaction costs— — — 19.3 
Write-off of previously suspended exploration wells— — — 13.2 
Impact of tax reform— (4.2)— (17.2)
Tax benefits on investments in foreign areas— — — (15.0)
Total adjustments after taxes158.2 133.2 949.1 58.7 
Adjusted (loss) income from continuing operations attributable to Murphy$(13.5)24.6 (192.5)143.9 
Adjusted (loss) income from continuing operations per average diluted share$(0.09)0.16 (1.25)0.87 
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
December 31, 2020		Year Ended
December 31, 2020
(Millions of dollars)
Pretax
Tax
Net
Pretax
Tax
Net
Exploration & Production:
United States
$19.2 (4.0)15.2 1,040.5 (219.8)820.7 
Canada — — — (1.7)0.4 (1.3)
Other International
— — — 39.7 — 39.7 
Total E&P
19.2 (4.0)15.2 1,078.5 (219.4)859.1 
Corporate:
180.6 (37.6)143.0 114.7 (24.7)90.0 
Total adjustments
$199.8 (41.6)158.2 1,193.2 (244.1)949.1 
14

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

Three Months Ended
December 31,		Year Ended
December 31,
(Millions of dollars, except per barrel of oil equivalents sold)
2020201920202019
Net (loss) income attributable to Murphy (GAAP)$(171.9)(71.7)(1,148.8)1,149.7 
Income tax (benefit) expense(44.9)(24.0)(293.7)14.7 
Interest expense, net44.5 74.2 169.4 219.3 
Depreciation, depletion and amortization expense ¹207.6 310.1 932.6 1,076.5 
EBITDA attributable to Murphy (Non-GAAP)$35.3 288.6 (340.5)2,460.2 
Impairment of assets ¹— — 1,072.5 — 
Mark-to-market (gain) loss on crude oil derivative contracts173.8 133.5 69.3 33.4 
Restructuring expenses3.6 — 50.0 — 
Accretion of asset retirement obligations10.9 10.7 42.1 40.5 
Unutilized rig charges2.8 — 16.0 — 
Mark-to-market (gain) loss on contingent consideration15.7 8.2 (13.8)8.7 
Inventory loss3.5 — 8.3 — 
Discontinued operations loss (income) 0.2 (36.9)7.2 (1,064.5)
Retirement obligation (gains) losses ¹(2.8)— (2.8)— 
Seal insurance proceeds— — (1.7)(8.0)
Foreign exchange (gains) losses 3.2 — 0.7 6.4 
Business development transaction costs— — — 24.4 
Write-off of previously suspended exploration wells— — — 13.2 
Adjusted EBITDA attributable to Murphy (Non-GAAP)$246.2 404.1 907.3 1,514.3 
Total barrels of oil equivalents sold from continuing operations attributable to Murphy (thousands of barrels)13,711 17,617 60,189 63,128 
Adjusted EBITDA per barrel of oil equivalents sold$17.96 22.94 15.07 23.99 
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 excludes the portion attributable to the non-controlling interest. Impairment of assets and retirement obligation gains used in the computation of Adjusted EBITDA exclude the portion attributable to the non-controlling interest.
15

MURPHY OIL CORPORATION
SCHEDULE OF EARNINGS BEFORE INTEREST, TAXES, DEPRECIATION
AND AMORTIZATION AND EXPLORATION (EBITDAX)
(unaudited)
Three Months Ended
December 31,		Year Ended
December 31,
(Millions of dollars, except per barrel of oil equivalents sold)
2020201920202019
Net (loss) income attributable to Murphy (GAAP)$(171.9)(71.7)(1,148.8)1,149.7 
Income tax (benefit) expense(44.9)(24.0)(293.7)14.7 
Interest expense, net44.5 74.2 169.4 219.3 
Depreciation, depletion and amortization expense ¹207.6 310.1 932.6 1,076.5 
EBITDA attributable to Murphy (Non-GAAP)35.3 288.6 (340.5)2,460.2 
Exploration expenses24.8 19.5 86.5 95.1 
EBITDAX attributable to Murphy (Non-GAAP)60.1 308.1 (254.0)2,555.3 
Impairment of assets ¹— — 1,072.5 — 
Mark-to-market (gain) loss on crude oil derivative contracts173.8 133.5 69.3 33.4 
Restructuring expenses3.6 — 50.0 — 
Accretion of asset retirement obligations10.9 10.7 42.1 40.5 
Unutilized rig charges2.8 — 16.0 — 
Mark-to-market (gain) loss on contingent consideration15.7 8.2 (13.8)8.7 
Inventory loss3.5 — 8.3 — 
Discontinued operations loss (income) 0.2 (36.9)7.2 (1,064.5)
Retirement obligation (gains) losses ¹(2.8)— (2.8)— 
Seal insurance proceeds— — (1.7)(8.0)
Foreign exchange (gains) losses 3.2 — 0.7 6.4 
Business development transaction costs— — — 24.4 
Adjusted EBITDAX attributable to Murphy (Non-GAAP)$271.0 423.6 993.8 1,596.2 
Total barrels of oil equivalents sold from continuing operations attributable to Murphy (thousands of barrels)13,711 17,617 60,189 63,128 
Adjusted EBITDAX per barrel of oil equivalents sold$19.77 24.04 16.51 25.29 
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 EBITDAX excludes the portion attributable to the non-controlling interest. Impairment of assets and retirement obligation gains used in the computation of Adjusted EBITDAX exclude the portion attributable to the non-controlling interest.
16

MURPHY OIL CORPORATION
FUNCTIONAL RESULTS OF OPERATIONS (unaudited)

Three Months Ended
December 31, 2020		Three Months Ended
December 31, 2019
(Millions of dollars)
RevenuesIncome
(Loss)		RevenuesIncome
(Loss)
Exploration and production
United States 1,2
$341.2 (2.6)632.7 98.4 
Canada100.6 — 123.2 3.2 
Other — (12.6)3.7 (18.1)
Total exploration and production441.8 (15.2)759.6 83.5 
Corporate(111.6)(147.3)(122.1)(174.8)
Revenue/income from continuing operations330.2 (162.5)637.5 (91.3)
Discontinued operations, net of tax 3
— (0.2)— 36.9 
Total revenues/net income (loss) including noncontrolling interest$330.2 (162.7)637.5 (54.4)
Net (loss) income attributable to Murphy(171.9)(71.7)

Year Ended
December 31, 2020		Year Ended
December 31, 2019
(Millions of dollars)
RevenuesIncome
(Loss)		RevenuesIncome
(Loss)
Exploration and production
United States 1,2
$1,411.8 (1,014.3)2,367.0 518.4 
Canada345.8 (35.0)447.0 (4.3)
Other 2
1.8 (85.6)11.6 (53.5)
Total exploration and production1,759.4 (1,134.9)2,825.6 460.6 
Corporate207.9 (120.3)3.5 (271.8)
Revenue/income from continuing operations1,967.3 (1,255.2)2,829.1 188.8 
Discontinued operations, net of tax 3
— (7.2)— 1,064.5 
Total revenues/net income (loss) including noncontrolling interest$1,967.3 (1,262.4)2,829.1 1,253.3 
Net (loss) income attributable to Murphy(1,148.8)1,149.7 
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 year ended December 31, 2020.
3 Malaysia is reported as discontinued operations in current and comparative periods effective January 1, 2019.
17

MURPHY OIL CORPORATION
OIL AND GAS OPERATING RESULTS (unaudited)
THREE MONTHS ENDED DECEMBER 31, 2020, AND 2019

(Millions of dollars)
United
States 1
Canada
Other
Total
Three Months Ended December 31, 2020
Oil and gas sales and other operating revenues$341.2 100.6 — 441.8 
Lease operating expenses90.4 31.0 0.4 121.8 
Severance and ad valorem taxes5.6 0.3 — 5.9 
Transportation, gathering and processing32.3 13.3 — 45.6 
Restructuring expenses1.2 — — 1.2 
Depreciation, depletion and amortization159.9 51.9 0.8 212.6 
Accretion of asset retirement obligations9.5 1.5 — 11.0 
Exploration expenses
Dry holes and previously suspended exploration costs12.8 — — 12.8 
Geological and geophysical— — 1.9 1.9 
Other exploration0.7 0.1 4.5 5.3 
13.5 0.1 6.4 20.0 
Undeveloped lease amortization2.4 0.1 2.3 4.8 
Total exploration expenses15.9 0.2 8.7 24.8 
Selling and general expenses8.0 3.9 1.6 13.5 
Other20.5 0.2 0.4 21.1 
Results of operations before taxes(2.1)(1.7)(11.9)(15.7)
Income tax provisions (benefits)0.5 (1.7)0.7 (0.5)
Results of operations (excluding Corporate segment)$(2.6)— (12.6)(15.2)
Three Months Ended December 31, 2019
Oil and gas sales and other operating revenues$632.7 123.2 3.7 759.6 
Lease operating expenses153.2 35.3 0.2 188.7 
Severance and ad valorem taxes10.6 0.4 — 11.0 
Transportation, gathering and processing37.4 10.2 — 47.6 
Depreciation, depletion and amortization260.1 61.4 0.6 322.1 
Accretion of asset retirement obligations9.2 1.5 — 10.7 
Exploration expenses
Geological and geophysical(2.3)0.1 6.8 4.6 
Other exploration2.3 0.2 6.4 8.9 
— 0.3 13.2 13.5 
Undeveloped lease amortization5.1 0.3 0.9 6.3 
Total exploration expenses5.1 0.6 14.1 19.8 
Selling and general expenses21.4 8.7 5.2 35.3 
Other14.7 0.8 0.4 15.9 
Results of operations before taxes121.0 4.3 (16.8)108.5 
Income tax provisions (benefits)22.6 1.1 1.3 25.0 
Results of operations (excluding Corporate segment)$98.4 3.2 (18.1)83.5 
1 Includes results attributable to a noncontrolling interest in MP GOM.
18

MURPHY OIL CORPORATION
OIL AND GAS OPERATING RESULTS (unaudited)
YEAR ENDED DECEMBER 31, 2020, AND 2019
(Millions of dollars)
United
States 1
Canada
Other
Total
Year Ended December 31, 2020
Oil and gas sales and other operating revenues$1,411.8 345.8 1.8 1,759.4 
Lease operating expenses476.9 121.6 1.6 600.1 
Severance and ad valorem taxes27.2 1.3 — 28.5 
Transportation, gathering and processing127.7 44.7 — 172.4 
Restructuring expenses1.2 — — 1.2 
Depreciation, depletion and amortization749.4 213.2 2.3 964.9 
Accretion of asset retirement obligations36.6 5.6 — 42.2 
Impairment of assets1,152.5 — 39.7 1,192.2 
Exploration expenses
Dry holes and previously suspended exploration costs21.1 — — 21.1 
Geological and geophysical9.4 0.1 6.0 15.5 
Other exploration5.0 0.5 17.6 23.1 
35.5 0.6 23.6 59.7 
Undeveloped lease amortization17.2 0.4 9.2 26.8 
Total exploration expenses52.7 1.0 32.8 86.5 
Selling and general expenses24.6 17.1 7.1 48.8 
Other21.5 (2.3)1.8 21.0 
Results of operations before taxes(1,258.5)(56.4)(83.5)(1,398.4)
Income tax provisions (benefits)(244.2)(21.4)2.1 (263.5)
Results of operations (excluding Corporate segment)$(1,014.3)(35.0)(85.6)(1,134.9)
Year Ended December 31, 2019
Oil and gas sales and other operating revenues$2,367.0 447.0 11.6 2,825.6 
Lease operating expenses461.5 142.4 1.3 605.2 
Severance and ad valorem taxes46.6 1.4 — 48.0 
Transportation, gathering and processing140.8 35.5 — 176.3 
Depreciation, depletion and amortization878.7 243.0 3.5 1,125.2 
Accretion of asset retirement obligations34.4 6.1 — 40.5 
Exploration expenses
Dry holes and previously suspended exploration costs(0.2)— 13.1 12.9 
Geological and geophysical13.8 0.1 14.9 28.8 
Other exploration7.8 0.5 17.3 25.6 
21.4 0.6 45.3 67.3 
Undeveloped lease amortization23.1 1.3 3.6 28.0 
Total exploration expenses44.5 1.9 48.9 95.3 
Selling and general expenses74.3 30.0 22.5 126.8 
Other52.2 (6.1)1.3 47.4 
Results of operations before taxes634.0 (7.2)(65.9)560.9 
Income tax provisions (benefits)115.6 (2.9)(12.4)100.3 
Results of operations (excluding Corporate segment)$518.4 (4.3)(53.5)460.6 
1 Includes results attributable to a noncontrolling interest in MP GOM.
19

MURPHY OIL CORPORATION
PRODUCTION-RELATED EXPENSES
(unaudited)

Three Months Ended
December 31,		Year Ended
December 31,
(Dollars per barrel of oil equivalents sold)
2020201920202019
Continuing operations
United States – Eagle Ford Shale
Lease operating expense
$9.49 8.11 9.08 8.70 
Severance and ad valorem taxes
1.97 2.32 2.06 2.82 
Depreciation, depletion and amortization (DD&A) expense
28.07 24.83 26.22 24.19 
United States – Gulf of Mexico
Lease operating expense 1
$9.65 13.84 11.95 10.89 
DD&A expense
12.27 17.47 13.48 16.43 
Canada – Onshore
Lease operating expense
$4.83 5.73 4.63 5.49 
Severance and ad valorem taxes
0.07 0.07 0.07 0.07 
DD&A expense
9.91 10.59 9.93 10.94 
Canada – Offshore
Lease operating expense 2
$22.44 9.76 17.86 14.95 
DD&A expense
14.12 12.30 12.01 13.07 
Total oil and gas continuing operations
Lease operating expense 3
$8.39 10.09 9.34 8.95 
Severance and ad valorem taxes
0.41 0.59 0.44 0.71 
DD&A expense
15.03 17.56 15.36 16.98 
Total oil and gas continuing operations – excluding noncontrolling interest
Lease operating expense
$8.21 9.76 9.10 8.81 
Severance and ad valorem taxes
0.43 0.62 0.47 0.76 
DD&A expense
15.14 17.60 15.49 17.05 
1 For the year ended December 31, 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 was $9.52. Workovers for the year ended December 31, 2020 included Dalmatian and Cascade. There were no significant Gulf of Mexico workovers in the fourth quarter 2020.
2 For the quarter and year ended December 31, 2020, Canada Offshore LOE per BOE excluding the costs associated with the Terra Nova life extension project was $6.38 and $5.24.
3 For the year ended December 31, 2020, total LOE per BOE excluding cost associated with Gulf of Mexico well workovers was $7.91. There were no significant Gulf of Mexico workovers in the fourth quarter 2020.



20

MURPHY OIL CORPORATION
OTHER FINANCIAL DATA
(unaudited)

Three Months Ended
December 31,		Year Ended
December 31,
(Millions of dollars)
2020201920202019
Capital expenditures for continuing operations
Exploration and production
United States $129.1 248.2 650.8 2,290.5 
Canada5.3 88.7 121.9 290.3 
Other7.9 25.7 40.6 102.4 
Total142.3 362.6 813.3 2,683.2 
Corporate4.0 6.5 13.3 15.0 
Total capital expenditures - continuing operations 1
146.3 369.1 826.6 2,698.2 
Charged to exploration expenses 2
United States13.5 — 35.5 21.4 
Canada0.1 0.3 0.6 0.6 
Other6.4 13.2 23.6 45.3 
Total charged to exploration expenses - continuing operations20.0 13.5 59.7 67.3 
Total capitalized $126.3 355.6 766.9 2,630.9 
1 For the three months and year ended December 31, 2020, includes noncontrolling interest (NCI) capital expenditures of $3.9 million and $21.7 million, respectively. Also, for the three months and year ended December 31, 2020, includes capital expenditures associated with the King’s Quay project of $12.0 million and $92.8 million, respectively. King’s Quay is classified as held for sale in the December 31, 2020 unaudited balance sheet.
2 Excludes amortization of undeveloped leases of $4.8 million and $6.3 million for each of the three months ended December 31, 2020 and 2019. Excludes amortization of undeveloped leases of $26.8 million and $28.0 million for the years ended December 31, 2020 and 2019, respectively.

21

MURPHY OIL CORPORATION
CONDENSED BALANCE SHEETS (unaudited)

(Millions of dollars)
December 31, 2020December 31, 2019
Assets
Cash and cash equivalents$310.6 306.8 
Assets held for sale327.7 123.9 
Other current assets 362.0 543.7 
Property, plant and equipment – net8,269.0 9,969.7 
Other long-term assets1,351.5 774.4 
Total assets$10,620.8 11,718.5 
Liabilities and Equity
Liabilities associated with assets held for sale$14.4 13.3 
Other current liabilities 701.9 929.5 
Long-term debt2,988.1 2,803.4 
Other long-term liabilities2,522.3 2,167.7 
Total equity 1,2
4,394.1 5,804.6 
Total liabilities and equity$10,620.8 11,718.5 
1 Includes noncontrolling interest of $179.8 million and $337.2 million as of December 31, 2020 and December 31, 2019, respectively.
2 Number of shares of Common Stock, $1.00 par value, outstanding at December 31, 2020 was 153,598,625.
22

MURPHY OIL CORPORATION
PRODUCTION SUMMARY
(unaudited)
Three Months Ended
December 31,		Year Ended
December 31,
Barrels per day unless otherwise noted2020201920202019
Continuing operations
Net crude oil and condensate
United StatesOnshore21,875 38,500 26,420 34,578 
Gulf of Mexico 1
56,648 74,409 64,680 66,823 
CanadaOnshore7,241 5,812 7,888 6,329 
Offshore4,170 7,257 4,893 6,543 
Other— 569 85 469 
Total net crude oil and condensate - continuing operations89,934 126,547 103,966 114,742 
Net natural gas liquids
United StatesOnshore4,620 6,056 5,248 5,731 
Gulf of Mexico 1
4,522 7,037 4,978 4,894 
CanadaOnshore1,325 1,457 1,315 1,263 
Total net natural gas liquids - continuing operations10,467 14,550 11,541 11,888 
Net natural gas – thousands of cubic feet per day
United StatesOnshore24,799 32,145 27,985 30,692 
Gulf of Mexico 1
60,909 75,922 66,105 52,068 
CanadaOnshore255,933 283,670 260,683 271,355 
Total net natural gas - continuing operations341,641 391,737 354,773 354,115 
Total net hydrocarbons - continuing operations including NCI 2,3
157,341 206,387 174,636 185,649 
Noncontrolling interest
Net crude oil and condensate – barrels per day(7,841)(11,255)(9,962)(11,226)
Net natural gas liquids – barrels per day(335)(539)(416)(507)
Net natural gas – thousands of cubic feet per day 2
(2,968)(4,059)(3,843)(3,965)
Total noncontrolling interest(8,671)(12,471)(11,019)(12,394)
Total net hydrocarbons - continuing operations excluding NCI 2,3
148,671 193,916 163,617 173,255 
Discontinued operations
Net crude oil and condensate – barrels per day— — — 12,215 
Net natural gas liquids – barrels per day— — — 325 
Net natural gas – thousands of cubic feet per day 2
— — — 50,758 
Total discontinued operations— — — 21,000 
Total net hydrocarbons produced excluding NCI 2,3
148,671 193,916 163,617 194,255 
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.
23

MURPHY OIL CORPORATION
PRICE SUMMARY
(unaudited)
Three Months Ended
December 31,		Year Ended
December 31,
2020201920202019
Weighted average Exploration and Production sales prices
Continuing operations
Crude oil and condensate – dollars per barrel
United StatesOnshore$40.26 57.18 $36.54 $59.45 
Gulf of Mexico 1
42.94 58.94 39.15 61.09 
Canada 2
Onshore39.52 51.32 32.42 50.29 
Offshore45.54 64.75 39.40 64.91 
Natural gas liquids – dollars per barrel
United StatesOnshore14.81 14.56 11.67 14.60 
Gulf of Mexico 1
15.61 13.57 10.84 15.10 
Canada 2
Onshore23.23 22.49 18.54 26.04 
Natural gas – dollars per thousand cubic feet
United StatesOnshore2.63 2.34 1.95 2.47 
Gulf of Mexico 1
2.46 2.39 2.04 2.43 
Canada 2
Onshore2.32 1.89 1.79 1.60 
1 Prices include the effect of noncontrolling interest share for MP GOM.
2 U.S. dollar equivalent.


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MURPHY OIL CORPORATION
COMMODITY HEDGE POSITIONS (unaudited)
AS OF JANUARY 26, 2021
CommodityTypeVolumes
(Bbl/d)		Price
(USD/Bbl)		Remaining Period
AreaStart DateEnd Date
United StatesWTI ¹Fixed price derivative swap45,000 $42.77 1/1/202112/31/2021
United StatesWTI ¹Fixed price derivative swap20,000 $44.88 1/1/202212/31/2022
1 West Texas Intermediate
Volumes
(MMcf/d)		Price
(CAD/Mcf)		Remaining Period
AreaCommodityTypeStart DateEnd Date
MontneyNatural GasFixed price forward sales at AECO160 C$2.541/1/20211/31/2021
MontneyNatural GasFixed price forward sales at AECO203 C$2.552/1/20215/31/2021
MontneyNatural GasFixed price forward sales at AECO212 C$2.556/1/202112/31/2021
MontneyNatural GasFixed price forward sales at AECO222 C$2.411/1/202212/31/2022
MontneyNatural GasFixed price forward sales at AECO192 C$2.361/1/202312/31/2023
MontneyNatural GasFixed price forward sales at AECO147 C$2.411/1/202412/31/2024

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MURPHY OIL CORPORATION
FIRST QUARTER 2021 GUIDANCE
Oil
BOPD		NGLs
BOPD		Gas
MCFD		Total
BOEPD
Production – net
U.S.  – Eagle Ford Shale20,600 4,300 23,400 28,800 
– Gulf of Mexico excluding NCI 50,900 5,800 68,500 68,100 
Canada – Tupper Montney— — 245,600 40,900 
– Kaybob Duvernay and Placid Montney6,100 1,200 21,000 10,800 
– Offshore4,400 — — 4,400 
Total net production (BOEPD) - excluding NCI 1
149,000 to 157,000
Exploration expense ($ millions)$15
FULL YEAR 2021 GUIDANCE
Total net production (BOEPD) - excluding NCI 2
155,000 to 165,000
Capital expenditures – excluding NCI ($ millions) 3
$675 to $725
¹ Excludes noncontrolling interest of MP GOM of 8,400 BOPD of oil, 600 BOPD of NGLs, and 5,000 MCFD gas.
² Excludes noncontrolling interest of MP GOM of 8,400 BOPD of oil, 600 BOPD of NGLs, and 4,700 MCFD gas.
³ Excludes noncontrolling interest of MP GOM of $43 MM.

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