Murphy Oil Corp. (MUR) filed Annual Report for the period ended 2011-12-31.
Murphy Oil has a market cap of $12.53 billion; its shares were traded at around $64.8 with a P/E ratio of 10.8 and P/S ratio of 0.5. The dividend yield of Murphy Oil stocks is 1.7%. Murphy Oil had an annual average earning growth of 18.4% over the past 10 years. GuruFocus rated Murphy Oil the business predictability rank of 3-star.
This is the annual revenues and earnings per share of MUR over the last 10 years. For detailed 10-year financial data and charts, go to 10-Year Financials of MUR.
Highlight of Business Operations:Sales and operating revenues were $7.5 billion more in 2011 than 2010 primarily due to higher prices realized on crude oil production and gasoline and other refined products sold by the Company. Gain on sale of assets classified in continuing operations was $21.8 million more in 2011 than 2010 principally due to a profit on sale of gas storage assets in Spain in the current year. Interest and other income (loss) in 2011 was favorable $90.5 million compared to 2010 principally due to improved income effects from transactions denominated in foreign currencies. Additionally, the Company collected higher interest income on invested cash balances in 2011 primarily due to larger average invested balances during the year. Crude oil and product purchases expense was $6.5 billion more in 2011 than 2010 due to higher costs of crude oil feedstocks at the Milford Haven, Wales refinery, higher costs for gasoline purchased for resale in the U.S. retail marketing operations and an increase in volume of merchandise purchased for resale at U.S. retail gasoline stations. Operating expenses in 2011 were $314.8 million more than 2010 mostly due to higher costs associated with the Companys production of oil and natural gas in 2011, plus higher operating expenses at U.S. retail marketing stations, and higher power and other costs at the Milford Haven, Wales refinery. Exploration expense in 2011 was $197.6 million above 2010 primarily due to higher dry hole costs associated with unsuccessful exploratory drilling activities in Brunei, Indonesia, Canada and Suriname. Selling and general expenses rose $41.8 million in 2011 compared to 2010 primarily due to a combination of higher costs for employee compensation and professional services. Depreciation, depletion and amortization expense was down $21.1 million in 2011 mostly due to fewer barrels of oil equivalent produced in 2011 compared to 2010. Impairment of long-lived assets of $368.6 million in 2011 was attributable to a charge to reduce the net book value of the Azurite oil field to fair value. The charge was necessitated by a reduction of proved oil reserves at this field at year-end 2011. Accretion of asset retirement obligations increased $5.8 million in 2011, primarily due to future abandonment costs to be incurred on oil and gas development wells drilled in the Eagle Ford Shale and Montney areas in 2011, and higher estimated abandonment costs for existing wells in the Gulf of Mexico and offshore Malaysia and for synthetic oil operations at Syncrude in Western Canada. The income effect of the redetermination of the Companys working interest at the Terra Nova field, offshore Eastern Canada, was favorable $23.9 million in 2011 compared to 2010. The final settlement related to the redetermination was made in early 2011 at a net cost to the Company that was $5.4 million less than previously estimated. The benefit from this reduced settlement payment was recognized in 2011. The net cost of $18.6 million in 2010 related to the portion of Terra Novas operating results in 2010 that were estimated to be owed to other partners upon final settlement. Due to the redetermination process, the Companys working interest at Terra Nova was reduced from 12.0% to 10.475%. Interest expense in 2011 was $2.7 million more than 2010 primarily due to interest associated with tax reassessments in Canada in the most recent year. Interest capitalized to oil and gas development projects in 2011 was $3.3 million below 2010 due to cessation of interest capitalized upon commencement of production at the Tupper West area in Western Canada in the first quarter 2011. Income tax expense was $200.9 million more in 2011 than 2010 due to higher pretax income in 2011 plus higher exploration and impairment expenses in the year for which no tax benefit was recognizable by the Company. The effective tax rate on a consolidated basis increased from 43.9% in 2010 to 52.2% in 2011 due to a larger percentage of earnings in higher tax jurisdictions in 2011 and due to higher exploration, impairment and other expenses in foreign jurisdictions where no income tax benefit can presently be recognized due to no assurance that these expenses would be realized in 2011 or future years to reduce taxes owed. The tax rates in both 2011 and 2010 were higher than the U.S. federal statutory rate of 35.0% due to a combination of U.S. state income taxes, certain foreign tax rates that exceeded the U.S. federal tax rate, and certain exploration and other expenses in foreign taxing jurisdictions for which no income tax benefit is currently being recognized because of the Companys uncertain ability to obtain tax benefits for these expenses in 2011 or future years. Income from discontinued operations was $113.2 million higher in 2011 than 2010 due to stronger U.S. refining margins in 2011 prior to the sale of the refineries near the end of the third quarter of 2011. Additionally, 2011 discontinued operations included a pretax gain on sale of the two U.S. refineries of $18.7 million.
The Companys average realized oil sales price of $94.54 in 2011 was an increase of 41% compared to 2010. The average price of West Texas Intermediate (WTI) crude oil rose 19% during 2011. The Companys average oil price increased more than WTI because other worldwide benchmark prices rose more than WTI during 2011. Dated Brent prices, for example, rose 40% during 2011. Additionally, the Companys realized sales price in Malaysia in 2011 and a portion of 2010 benefited from a switch to the Brent benchmark price during the prior year. Crude oil prices strengthened in 2011 due to an improvement in energy demand in association with a slowly recovering worldwide economy and unrest in Northern Africa and the Middle East during 2011 that caused concern in the oil markets about the potential for supply disruptions. Compared to 2010, the Companys average 2011 crude oil sales prices in the U.S. rose 36% to $103.92 per barrel; heavy oil prices in Canada sold for 14% more and averaged $57.00 per barrel; offshore Canada prices increased 43% to $110.02 per barrel; synthetic crude oil sold for 32% more at $102.94 per barrel; crude oil in Malaysia was up 48% and averaged $90.14 per barrel; U.K. crude oil production sold for 41% more at $110.13 per barrel; and crude oil in Republic of the Congo sold at $103.02 per barrel in 2011, an increase of 38% from 2010.
The average realized crude oil sales price increased 19% in 2010 compared to 2009. The higher price for 2010 was slightly below the 28% increase in WTI sales price between the years. Other benchmark oil prices used for sale of Company crude oil did not increase at the same rate as WTI. The increase in the sales price for APPI Tapis based crude oil during 2010 did not keep pace with the increase in the WTI price due to differences in market conditions in Asia versus the U.S. During most of 2010, the Company sold its Kikeh crude oil based on the APPI Tapis benchmark price. In late 2010, the Company began to sell its Kikeh crude oil based on a Brent crude oil benchmark. Compared to 2009, the Companys average 2010 crude oil sales prices rose 27% in the U.S. to average $76.31 per barrel; heavy oil sales prices in Canada rose 23% to an average of $49.89 per barrel; offshore Canada oil sold at $76.87 per barrel, an increase of 32%; Canadian synthetic crude oil sold for 27% more and averaged $77.90 per barrel; crude oil produced in Malaysia increased 10% to an average price of $60.97 per barrel; U.K. crude oil prices increased 27% to $77.95 per barrel; and crude oil sold in Republic of the Congo increased only 8% to $74.87 per barrel as the only sale in 2009 was near the end of the year when prices were above the 2009 average.
Investing activities Cash proceeds from property sales classified as continuing operations were $27.8 million in 2011, $2.2 million in 2010 and $1.6 million in 2009. The 2011 proceeds primarily related to sale of gas storage assets in Spain. In 2011, the Company generated cash of $950.0 million from sale of two U.S. refineries and associated marketing assets, including liquid inventories. The U.S. refineries operating results and cash flow have been classified as discontinued operations in the Companys consolidated financial statements. Other investing activities for discontinued operations included capital expenditures of $48.1 million in 2011, $117.3 million in 2010 and $113.3 million in 2009. Additionally, the two U.S. refineries which were sold used cash of $1.5 million in 2011, $37.5 million in 2010 and $10.2 million in 2009 for maintenance turnarounds. During 2009, the Company generated cash of $78.9 million from the sale of its 20% working interest in Block 16 in Ecuador. Operating results and cash flows associated with Ecuador operations have also been classified as discontinued operations. Property additions and dry hole costs for continuing operations used cash of $2.62 billion in 2011, $2.24 billion in 2010 and $1.88 billion in 2009. Cash used to pay for capital expenditures increased each year compared to the prior year, with these variances essentially in line with changes in capital expenditures in each year. Cash of $1.69 billion, $2.39 billion and $2.53 billion was spent in 2011, 2010 and 2009, respectively, to acquire Canadian government securities with maturities greater than 90 days at the time of purchase. Proceeds from maturities of Canadian government securities with maturities greater than 90 days at date of acquisition were $1.77 billion in 2011, $2.55 billion in 2010 and $2.17 billion in 2009. Cash of $5.4 million in 2011, $61.4 million in 2010 and $19.3 million in 2009 was used for turnarounds at the Milford Haven, Wales, refinery and Syncrude. The higher spend in 2010 was attributable to a plant-wide turnaround at Milford Haven.
Other changes in Murphys year-end 2011 balance sheet compared to 2010 included an $84.5 million reduction in the balance of short-term investments in Canadian government securities with maturities greater than 90 days at the time of purchase. The total investment in these Canadian government securities was $532.1 million at year-end 2011 and $616.6 million at year-end 2010. These slightly longer-term investments were purchased in each year because of a tight supply of shorter-term securities available for purchase in Canada. An $86.9 million increase in accounts receivable in 2011 was primarily caused by higher sales prices for crude oil and finished products sold, and higher natural gas sales volumes sold on credit terms by the Company, but partially offset by the sale of U.S. refineries in 2011, which effectively reduced refined products volumes sold under credit arrangements in the U.S. in 2011. Inventory values were $95.6 million less at year-end 2011 than in 2010 mostly due to lower levels of crude oil and refined products held in storage within downstream operations in the later year due to sale of two refineries in the U.S., but partially offset by higher costs for unsold crude oil production held in inventory in the current year. Prepaid expenses increased $5.2 million in 2011 primarily due to prepaid income taxes in the U.S. at year-end 2011. Short-term deferred income tax assets were $6.9 million higher at year-end 2011 compared to 2010 due mostly to more current temporary differences for expense deductions within U.K. downstream operations. Net property, plant and equipment increased by $107.3 million in 2011 as a significant level of property additions during the year exceeded the amounts of depreciation, amortization and impairment expenses recorded during 2011. Goodwill decreased $1.0 million in 2011 due to a weaker Canadian dollar exchange rate versus the U.S. dollar. Deferred charges and other assets decreased $98.4 million mostly due to no deferred turnaround costs and other noncurrent assets remaining for the Meraux and Superior refineries following their sale in 2011. Current maturities of long-term debt at year-end 2011 was $350.0 million higher than at the prior year-end due to a reclassification of $350.0 million of outstanding notes payable to current based on their upcoming maturity in May 2012. Accounts payable decreased by $296.9 million at year-end 2011 compared to 2010 primarily due to lower amounts owed for purchased crude oil feedstocks following the sale of the U.S. refineries in 2011. Income taxes payable was $157.0 million lower at year-end 2011 than at the end of 2010, primarily due to less U.S. income tax liabilities owed in 2011. Other taxes payable at year-end 2011 was $37.4 million lower than in 2010 mostly due to less value added taxes owed by the U.K. downstream operations