Enter data into the FSAP (Financial Statement Analysis Package) Excel File.Enter the balance sheet and income statement amounts for 2012 for Exxon Mobile.

Document And Entity Information (USD $) 12 Months Ended In Billions, except Share data, unless otherwise specified Document And Entity Information [Abstract] Document Type Amendment Flag Document Period End Date Document Fiscal Period Focus Document Fiscal Year Focus Trading Symbol Entity Registrant Name Entity Central Index Key Current Fiscal Year End Date Entity Well-known Seasoned Issuer Entity Current Reporting Status Entity Voluntary Filers Entity Filer Category Entity Common Stock, Shares Outstanding Entity Public Float Dec. 31, 2012 Jan. 31, 2013 Jun. 30, 2012 10-K 0 31-Dec-12 FY 2012 XOM EXXON MOBIL CORP 34088 -19 Yes Yes No Large Accelerated Filer 4,480,449,635 $394 Consolidated Statement Of Income (USD $) In Millions, except Per Share data, unless otherwise specified Revenues and other income Sales and other operating revenue Income from equity affiliates Other income Total revenues and other income Costs and other deductions Crude oil and product purchases Production and manufacturing expenses Selling, general and administrative expenses Depreciation and depletion Exploration expenses, including dry holes Interest expense Sales-based taxes Other taxes and duties Total costs and other deductions Income before income taxes Income taxes Net income including noncontrolling interests Net income attributable to noncontrolling interests Net income attributable to ExxonMobil Earnings per common share (dollars) Earnings per common share - assuming dilution (dollars) [1] [2] 12 M Dec. 31, 2012 $453,123 [1],[2] 15,010 14,162 482,295 265,149 38,521 13,877 15,888 1,840 327 32,409 [1] 35,558 403,569 78,726 31,045 47,681 2,801 $44,880 $9.70 $9.70 Sales and other operating revenue includes sales-based taxes of $32,409 mil Sales and other operating revenue includes sales-based taxes of $32,409 mil Summary of Accounting Policies. 12 Months Ended Dec. 31, 2011 $467,029 [1],[2] 15,289 4,111 486,429 Dec. 31, 2010 $370,125 [1],[2] 10,677 2,419 383,221 266,534 197,959 40,268 35,792 14,983 15,583 14,683 14,760 2,081 247 2,144 259 33,503 [1] 39,973 413,172 73,257 31,051 28,547 [1] 36,118 330,262 52,959 21,561 42,206 31,398 1,146 $41,060 $8.43 938 $30,460 $6.24 $8.42 $6.22 es sales-based taxes of $32,409 million for 2012, $33,503 million for 2011 and $28,547 million for 2010. es sales-based taxes of $32,409 million for 2012, $33,503 million for 2011 and $28,547 million for 2010. See Note 1, Consolidated Statement Of Income (Parenthetical) (USD $) In Millions, unless otherwise specified Consolidated Statement Of Income [Abstract] Sales and other operating revenue, salesbased taxes [1] 12 M Dec. 31, 2012 $32,409 [1] Sales and other operating revenue includes sales-based taxes of $32,409 mil 12 Months Ended Dec. 31, 2011 $33,503 Dec. 31, 2010 [1] $28,547 es sales-based taxes of $32,409 million for 2012, $33,503 million for 2011 and $28,547 million for 2010. [1] Consolidated Statement Of Comprehensive 12 Months Ended Income (USD $) In Millions, unless otherwise specified Dec. 31, 2012 Dec. 31, 2011 Dec. 31, 2010 Consolidated Statement Of Comprehensive Income [Abstract] Net income including noncontrolling interests Other comprehensive income (net of income taxes) $47,681 $42,206 $31,398 920 -867 1,034 Foreign exchange translation adjustment Adjustment for foreign exchange translation (gain)/loss included in net income Postretirement benefits reserves adjustment (excluding amortization) Amortization and settlement of postretirement benefits reserves adjustment included in net periodic benefit costs Change in fair value of cash flow hedges -4,352 -3,574 -4,907 -1,161 2,395 1,217 1,040 28 184 -4,611 -83 -4,612 -129 993 43,070 37,594 32,391 1,251 834 1,293 $41,819 $36,760 $31,098 Realized (gain)/ loss from settled cash flow hedges included in net income Total other comprehensive income Comprehensive income including noncontrolling interests Comprehensive income attributable to noncontrolling interests Comprehensive income attributable to ExxonMobil 25 Consolidated Balance Sheet (USD $) In Millions, unless otherwise specified Current assets Cash and cash equivalents Cash and cash equivalents - restricted Notes and accounts receivable, less estimated doubtful amounts Dec. 31, 2012 Dec. 31, 2011 Inventories Crude oil, products and merchandise Materials and supplies Other current assets Total current assets Investments, advances and long-term receivables Property, plant and equipment, at cost, less accumulated depreciation and depletion Other assets, including intangibles, net Total assets Current liabilities Notes and loans payable Accounts payable and accrued liabilities Income taxes payable Total current liabilities Long-term debt Postretirement benefits reserves Deferred income tax liabilities Long-term obligations to equity companies Other long-term obligations Total liabilities Commitments and contingencies Equity Common stock without par value (9,000 million shares authorized, 8,019 million shares issued) Earnings reinvested Accumulated other comprehensive income Common stock held in treasury (3,517 million shares in 2012 and 3,285 million shares in 2011) ExxonMobil share of equity Noncontrolling interests Total equity $9,582 341 $12,664 404 34,987 38,642 10,836 3,706 5,008 64,460 11,665 3,359 6,229 72,963 34,718 34,333 226,949 7,668 333,795 214,664 9,092 331,052 3,653 7,711 50,728 9,758 64,139 7,928 25,267 37,570 57,067 12,727 77,505 9,322 24,994 36,618 3,555 23,676 162,135 1,808 20,061 170,308 9,653 365,727 9,512 330,939 -12,184 -9,123 -197,333 165,863 5,797 171,660 -176,932 154,396 6,348 160,744 Total liabilities and equity $333,795 $331,052 Consolidated Balance Sheet (Parenthetical) (USD $) Consolidated Balance Sheet [Abstract] Common stock, without par value Common stock, shares authorized Common stock, shares issued Common stock held in treasury, shares Dec. 31, 2012 Dec. 31, 2011 9,000,000,000 9,000,000,000 8,019,000,000 8,019,000,000 3,517,000,000 3,285,000,000 Consolidated Statement Of Cash Flows (USD 12 Months Ended $) In Millions, unless otherwise specified Dec. 31, 2012 Dec. 31, 2011 Dec. 31, 2010 Cash flows from operating activities Net income including noncontrolling interests $47,681 $42,206 $31,398 Adjustments for noncash transactions Depreciation and depletion 15,888 15,583 14,760 Deferred income tax charges/(credits) 3,142 142 -1,135 Postretirement benefits expense in excess of/(less than) net payments -315 544 1,700 Other long-term obligation provisions in excess of/(less than) payments 1,643 -151 160 Dividends received greater than/(less than) equity in current earnings of equity companies -1,157 -273 -596 Changes in operational working capital, excluding cash and debt Reduction/(increase) - Notes and accounts receivable - Inventories - Other current assets Increase/(reduction) - Accounts and other payables Net (gain) on asset sales All other items - net Net cash provided by operating activities Cash flows from investing activities Additions to property, plant and equipment Proceeds associated with sales of subsidiaries, property, plant and equipment, and sales and returns of investments Decrease/(increase) in restricted cash and cash equivalents Additional investments and advances Collection of advances Additions to marketable securities Sales of marketable securities Net cash used in investing activities Cash flows from financing activities Additions to long-term debt Reductions in long-term debt Additions to short-term debt Reductions in short-term debt -1,082 -1,873 -42 -7,906 -2,208 222 -5,863 -1,148 913 3,624 -13,018 1,679 8,880 -2,842 1,148 9,943 -1,401 -318 56,170 55,345 48,413 -34,271 -30,975 -26,871 7,655 11,133 3,261 63 -972 1,924 -25,601 224 -3,586 1,119 -1,754 1,674 -22,165 -628 -1,239 1,133 -15 155 -24,204 995 -147 958 -4,488 702 -266 1,063 -1,103 1,143 -6,224 598 -2,436 Additions/(reductions) in debt with three months or less maturity Cash dividends to ExxonMobil shareholders Cash dividends to noncontrolling interests Changes in noncontrolling interests Tax benefits related to stock-based awards Common stock acquired Common stock sold Net cash used in financing activities Effects of exchange rate changes on cash Increase/(decrease) in cash and cash equivalents Cash and cash equivalents at beginning of year Cash and cash equivalents at end of year -226 1,561 709 -10,092 -9,020 -8,498 -327 204 -306 -16 -281 -7 130 -21,068 193 -33,868 260 -22,055 924 -28,256 122 -13,093 1,043 -26,924 217 -85 -153 -3,082 4,839 -2,868 12,664 7,825 10,693 $9,582 $12,664 $7,825 Consolidated Statement Of Changes In Equity (USD $) In Millions Balance at Dec. 31, 2009 Balance (in shares) at Dec. 31, 2009 Amortization of stock-based awards Tax benefits related to stock-based awards Other Net income for the year Dividends - common shares Other comprehensive income Acquisitions, at cost Issued for XTO merger Dispositions Acquisitions (in shares) Issued for XTO merger (in shares) Dispositions (in shares) Balance at Dec. 31, 2010 Balance (in shares) at Dec. 31, 2010 Amortization of stock-based awards Tax benefits related to stock-based awards Other Net income for the year Dividends - common shares Other comprehensive income Acquisitions, at cost Dispositions Acquisitions (in shares) Dispositions (in shares) Balance at Dec. 31, 2011 Balance (in shares) at Dec. 31, 2011 Amortization of stock-based awards Tax benefits related to stock-based awards Other Net income for the year Dividends - common shares Other comprehensive income Acquisitions, at cost Dispositions Acquisitions (in shares) Dispositions (in shares) Balance at Dec. 31, 2012 Total Exxon Mobil Share Of Common Stock [Member] USD ($) $115,392 USD ($) 751 280 -673 31,398 -8,779 993 -13,098 24,659 1,756 152,679 742 $5,503 8,019 751 280 -683 3,520 9,371 8,019 742 202 -808 42,206 -9,326 -4,612 -22,070 1,731 202 -803 160,744 9,512 8,019 806 806 178 -2,284 47,681 -10,419 -4,611 -21,102 667 178 -843 $171,660 $9,653 Balance (in shares) at Dec. 31, 2012 8,019 Exxon Mobil Share Of Earnings Reinvested [Member] Exxon Mobil Share Of Accumulated Other Comprehensive Income [Member] USD ($) USD ($) $276,937 ($5,461) 30,460 -8,498 638 298,899 -4,823 41,060 -9,020 -4,300 330,939 -9,123 44,880 -10,092 -3,061 $365,727 ($12,184) Exxon Mobil Share Of Common Stock Held In Treasury [Member] Exxon Mobil Share Of Equity [Member] USD ($) USD ($) ($166,410) -3,292 $110,569 751 -13,093 21,139 1,756 -199 416 35 -156,608 -3,040 280 -683 30,460 -8,498 638 -13,093 24,659 1,756 146,839 742 -22,055 1,731 -278 33 -176,932 -3,285 202 -803 41,060 -9,020 -4,300 -22,055 1,731 154,396 806 -21,068 667 -244 12 ($197,333) 178 -843 44,880 -10,092 -3,061 -21,068 667 $165,863 -3,517 Noncontrolling Interest [Member] Common Stock Outstanding [Member] USD ($) $4,823 4,727 10 938 -281 355 -5 -199 416 35 5,840 4,979 -5 1,146 -306 -312 -15 -278 33 6,348 4,734 -1,441 2,801 -327 -1,550 -34 -244 12 $5,797 4,502 Summary Of Accounting Policies 12 Months Ended Dec. 31, 2012 Summary Of Accounting Policies [Abstract] Summary Of Accounting Policies 1. Summary of Accounting Policies Principles of Consolidation. The Consolidated Financial Statements include the accounts of subsidiaries the Corporation controls. They also include the Corporation's share of the undivided interest in certain upstream assets and liabilities. Amounts representing the Corporation's interest in entities that it does not control, but over which it exercises significant influence, are included in \"Investments, advances and long-term receivables.\" The Corporation's share of the net income of these companies is included in the Consolidated Statement of Income caption \"Income from equity affiliates.\" Majority ownership is normally the indicator of control that is the basis on which subsidiaries are consolidated. However, certain factors may indicate that a majority-owned investment is not controlled and therefore should be accounted for using the equity method of accounting. These factors occur where the minority shareholders are granted by law or by contract substantive participating rights. These include the right to approve operating policies, expense budgets, financing and investment plans, and management compensation and succession plans. The Corporation's share of the cumulative foreign exchange translation adjustment for equity method investments is reported in Accumulated Other Comprehensive Income. Evidence of loss in value that might indicate impairment of investments in companies accounted for on the equity method is assessed to determine if such evidence represents a loss in value of the Corporation's investment that is other than temporary. Examples of key indicators include a history of operating losses, a negative earnings and cash flow outlook, significant downward revisions to oil and gas reserves, and the financial condition and prospects for the investee's business segment or geographic region. If evidence of an other than temporary loss in fair value below carrying amount is determined, an impairment is recognized. In the absence of market prices for the investment, discounted cash flows are used to assess fair value. Revenue Recognition. The Corporation generally sells crude oil, natural gas and petroleum and chemical products under short-term agreements at prevailing market prices. In some cases (e.g., natural gas), products may be sold under longterm agreements, with periodic price adjustments. Revenues are recognized when the products are delivered, which occurs when the customer has taken title and has assumed the risks and rewards of ownership, prices are fixed or determinable and collectibility is reasonably assured. Revenues from the production of natural gas properties in which the Corporation has an interest with other producers are recognized on the basis of the Corporation's net working interest. Differences between actual production and net working interest volumes are not significant. Purchases and sales of inventory with the same counterparty that are entered into in contemplation of one another are combined and recorded as exchanges measured at the book value of the item sold. Sales-Based Taxes. The Corporation reports sales, excise and value-added taxes on sales transactions on a gross basis in the Consolidated Statement of Income (included in both revenues and costs). Derivative Instruments. The Corporation makes limited use of derivative instruments. The Corporation does not engage in speculative derivative activities or derivative trading activities, nor does it use derivatives with leveraged features. When the Corporation does enter into derivative transactions, it is to offset exposures associated with interest rates, foreign currency exchange rates and hydrocarbon prices that arise from existing assets, liabilities and forecasted transactions. The gains and losses resulting from changes in the fair value of derivatives are recorded in income. In some cases, the Corporation designates derivatives as fair value hedges, in which case the gains and losses are offset in income by the gains and losses arising from changes in the fair value of the underlying hedged item. Fair Value. Fair value is the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants. Hierarchy Levels 1, 2 and 3 are terms for the priority of inputs to valuation techniques used to measure fair value. Hierarchy Level 1 inputs are quoted prices in active markets for identical assets or liabilities. Hierarchy Level 2 inputs are inputs other than quoted prices included within Level 1 that are directly or indirectly observable for the asset or liability. Hierarchy Level 3 inputs are inputs that are not observable in the market. Inventories. Crude oil, products and merchandise inventories are carried at the lower of current market value or cost (generally determined under the last-in, first-out method - LIFO). Inventory costs include expenditures and other charges (including depreciation) directly and indirectly incurred in bringing the inventory to its existing condition and location. Selling expenses and general and administrative expenses are reported as period costs and excluded from inventory cost. Inventories of materials and supplies are valued at cost or less. Property, Plant and Equipment. Depreciation, depletion and amortization, based on cost less estimated salvage value of the asset, are primarily determined under either the unit-of-production method or the straight-line method, which is based on estimated asset service life taking obsolescence into consideration. Maintenance and repairs, including planned major maintenance, are expensed as incurred. Major renewals and improvements are capitalized and the assets replaced are retired. Interest costs incurred to finance expenditures during the construction phase of multiyear projects are capitalized as part of the historical cost of acquiring the constructed assets. The project construction phase commences with the development of the detailed engineering design and ends when the constructed assets are ready for their intended use. Capitalized interest costs are included in property, plant and equipment and are depreciated over the service life of the related assets. The Corporation uses the \"successful efforts\" method to account for its exploration and production activities. Under this method, costs are accumulated on a field-by-field basis with certain exploratory expenditures and exploratory dry holes being expensed as incurred. Costs of productive wells and development dry holes are capitalized and amortized on the unit-ofproduction method. The Corporation carries as an asset exploratory well costs when the well has found a sufficient quantity of reserves to justify its completion as a producing well and where the Corporation is making sufficient progress assessing the reserves and the economic and operating viability of the project. Exploratory well costs not meeting these criteria are charged to expense. Other exploratory expenditures, including geophysical costs and annual lease rentals, are expensed as incurred. Acquisition costs of proved properties are amortized using a unit-of-production method, computed on the basis of total proved oil and gas reserves. Capitalized exploratory drilling and development costs associated with productive depletable extractive properties are amortized using unit-ofproduction rates based on the amount of proved developed reserves of oil, gas and other minerals that are estimated to be recoverable from existing facilities using current operating methods. Under the unit-of-production method, oil and gas volumes are considered produced once they have been measured through meters at custody transfer or sales transaction points at the outlet valve on the lease or field storage tank. Production costs are expensed as incurred. Production involves lifting the oil and gas to the surface and gathering, treating, field processing and field storage of the oil and gas. The production function normally terminates at the outlet valve on the lease or field production storage tank. Production costs are those incurred to operate and maintain the Corporation's wells and related equipment and facilities. They become part of the cost of oil and gas produced. These costs, sometimes referred to as lifting costs, include such items as labor costs to operate the wells and related equipment; repair and maintenance costs on the wells and equipment; materials, supplies and energy costs required to operate the wells and related equipment; and administrative expenses related to the production activity. Proved oil and gas properties held and used by the Corporation are reviewed for impairment whenever events or changes in circumstances indicate that the carrying amounts may not be recoverable. Assets are grouped at the lowest level for which there are identifiable cash flows that are largely independent of the cash flows of other groups of assets. The Corporation estimates the future undiscounted cash flows of the affected properties to judge the recoverability of carrying amounts. Cash flows used in impairment evaluations are developed using annually updated corporate plan investment evaluation assumptions for crude oil commodity prices, refining and chemical margins and foreign currency exchange rates. Annual volumes are based on field production profiles, which are also updated annually. Prices for natural gas and other products are based on corporate plan assumptions developed annually by major region and also for investment evaluation purposes. Cash flow estimates for impairment testing exclude derivative instruments. Impairment analyses are generally based on proved reserves. Where probable reserves exist, an appropriately risk-adjusted amount of these reserves may be included in the impairment evaluation. An asset group would be impaired if the undiscounted cash flows were less than its carrying value. Impairments are measured by the amount the carrying value exceeds fair value. Significant unproved properties are assessed for impairment individually, and valuation allowances against the capitalized costs are recorded based on the estimated economic chance of success and the length of time that the Corporation expects to hold the properties. Properties that are not individually significant are aggregated by groups and amortized based on development risk and average holding period. The valuation allowances are reviewed at least annually. Gains on sales of proved and unproved properties are only recognized when there is neither uncertainty about the recovery of costs applicable to any interest retained nor any substantial obligation for future performance by the Corporation. Losses on properties sold are recognized when incurred or when the properties are held for sale and the fair value of the properties is less than the carrying value. Asset Retirement Obligations and Environmental Liabilities. The Corporation incurs retirement obligations for certain assets. The fair values of these obligations are recorded as liabilities on a discounted basis, which is typically at the time the assets are installed. The costs associated with these liabilities are capitalized as part of the related assets and depreciated. Over time, the liabilities are accreted for the change in their present value. Liabilities for environmental costs are recorded when it is probable that obligations have been incurred and the amounts can be reasonably estimated. These liabilities are not reduced by possible recoveries from third parties and projected cash expenditures are not discounted. Foreign Currency Translation. The Corporation selects the functional reporting currency for its international subsidiaries based on the currency of the primary economic environment in which each subsidiary operates. Downstream and Chemical operations primarily use the local currency. However, the U.S. dollar is used in countries with a history of high inflation (primarily in Latin America) and Singapore, which predominantly sells into the U.S. dollar export market. Upstream operations which are relatively self-contained and integrated within a particular country, such as Canada, the United Kingdom, Norway and continental Europe, use the local currency. Some Upstream operations, primarily in Asia and Africa, use the U.S. dollar because they predominantly sell crude and natural gas production into U.S. dollar-denominated markets. For all operations, gains or losses from remeasuring foreign currency transactions into the functional currency are included in income. Stock-Based Payments. The Corporation awards stock-based compensation to employees in the form of restricted stock and restricted stock units. Compensation expense is measured by the market price of the restricted shares at the date of grant and is recognized in the income statement over the requisite service period of each award. See Note 15, Incentive Program, for further details. Accounting Changes Accounting Changes [Abstract] Accounting Changes 12 Months Ended Dec. 31, 2012 2. Accounting Changes The Corporation did not adopt authoritative guidance in 2012 that had a material impact on the Corporation's financial statements. 12 M De Miscellaneous Financial Information Miscellaneous Financial Information [Abstract] Miscellaneous Financial Information 3. Miscellaneous Financial Information Research and development expenses totaled $1,042 million in 2012, $1,044 million i Net income included before-tax aggregate foreign exchange transaction gains of $15 In 2012, 2011 and 2010, net income included gains of $328 million, $292 million an accumulations and drawdowns. The aggregate replacement cost of inventories was es December 31, 2012, and 2011, respectively. Crude oil, products and merchandise as of year-end 2012 and 2011 consist of the foll Petroleum products Crude oil Chemical products Gas/other Total 12 Months Ended Dec. 31, 2012 ,042 million in 2012, $1,044 million in 2011 and $1,012 million in 2010. gn exchange transaction gains of $159 million, and losses of $184 million and $251 million in 2012, 2011 and 2010, respectively. ains of $328 million, $292 million and $317 million, respectively, attributable to the combined effects of LIFO inventory replacement cost of inventories was estimated to exceed their LIFO carrying values by $21.3 billion and $25.6 billion at -end 2012 and 2011 consist of the following: 2012 2011 (billions of dollars) 3.6 4 2.9 4.1 4.8 2.3 0.3 0.5 10.8 11.7 12 M De Other Comprehensive Income Information Other Comprehensive Income Information [Abstract] Other Comprehensive Income Information 4. Other Comprehensive Income Information ExxonMobil Share of Accumulated Other Comprehensive Income Balance as of December 31, 2009 Current period change excluding amounts reclassified from accumulated other comprehensive income Amounts reclassified from accumulated other comprehensive income Total change in accumulated other comprehensive income Balance as of December 31, 2010 Balance as of December 31, 2010 Current period change excluding amounts reclassified from accumulated other comprehensive income Amounts reclassified from accumulated other comprehensive income Total change in accumulated other comprehensive income Balance as of December 31, 2011 Balance as of December 31, 2011 Current period change excluding amounts reclassified from accumulated other comprehensive income Amounts reclassified from accumulated other comprehensive income Total change in accumulated other comprehensive income Balance as of December 31, 2012 Income Tax (Expense)/Credit For Components of Other Comprehensive Income Foreign exchange translation adjustment Postretirement benefits reserves adjustment Postretirement benefits reserves adjustment (excluding amortization) Amortization and settlement of postretirement benefits reserves Unrealized change in fair value on cash flow hedges Change in fair value of cash flow hedges Settled cash flow hedges included in net income Total 12 Months Ended Dec. 31, 2012 er Comprehensive Income Information Cumulative Post- Unrealized Foreign retirement Change in Exchange Benefits Fair Value bil Share of Accumulated Other Translation Reserves on Cash ensive Income Adjustment Adjustment Flow Hedges (millions of dollars) s of December 31, 2009 eriod change excluding amounts reclassified from accumulated other comprehensive income reclassified from accumulated other 4,402 -9,863 - 584 -1,014 184 25 988 -129 609 -26 55 s of December 31, 2010 5,011 -9,889 55 s of December 31, 2010 eriod change excluding amounts reclassified from accumulated other comprehensive income reclassified from accumulated other 5,011 -9,889 55 -843 -4,557 28 - 1,155 -83 -843 -3,402 -55 s of December 31, 2011 4,168 -13,291 - s of December 31, 2011 eriod change excluding amounts reclassified from accumulated other comprehensive income reclassified from accumulated other 4,168 -13,291 - 842 -3,402 - -2,600 2,099 - -1,758 -1,303 - 2,410 -14,594 - comprehensive income ge in accumulated other comprehensive income comprehensive income ge in accumulated other comprehensive income comprehensive income ge in accumulated other comprehensive income s of December 31, 2012 ax (Expense)/Credit For nts of Other Comprehensive Income xchange translation adjustment ment benefits reserves adjustment 2012 2011 2010 (millions of dollars) -236 89 -42 Postretirement benefits reserves adjustment (excluding amortization) Amortization and settlement of postretirement benefits reserves adjustment included in net periodic benefit costs d change in fair value on cash flow hedges Change in fair value of cash flow hedges Settled cash flow hedges included in net income 1,619 2,039 689 -1,226 -544 -654 - -16 -113 - 50 79 157 1,618 -41 Unrealized Change in Fair Value on Cash Flow Hedges Total millions of dollars) -5,461 -246 884 638 -4,823 -4,823 -5,372 1,072 -4,300 -9,123 -9,123 -2,560 -501 -3,061 -12,184 Cash Flow Information Cash Flow Information [Abstract] Cash Flow Information 5. Cash Flow Information The Consolidated Statement of Cash Flows provides information about changes in cash and c as cash equivalents. The \"Net (gain) on asset sales\" in net cash provided by operating activities on the Consolidat property in Angola, exchanges of Upstream properties, the sale of U.S. service stations, and t Canadian, U.K. and other producing properties and assets, and the sale of U.S. service station service stations and other Downstream assets and investments and the formation of a Chemic In 2012, the Corporation's interest in a cost company was redeemed. As part of the redemptio ExxonMobil affiliate. This note is no longer classified as third party long-term debt. This ass In 2012, ExxonMobil completed asset exchanges, primarily noncash transactions, of approxi equipment\" or the \"Additions to property, plant and equipment\" lines on the Statement of Ca In 2011, included in \"Proceeds associated with sales of subsidiaries, property, plant and equip In 2010, the Corporation acquired all the outstanding equity of XTO Energy Inc. in an all-sto Cash payments for interest Cash payments for income taxes 12 Months Ended Dec. 31, 2012 Flows provides information about changes in cash and cash equivalents. Highly liquid investments with maturities of three months or less when acqu t cash provided by operating activities on the Consolidated Statement of Cash Flows includes before-tax gains from the Japan restructuring, the sale o stream properties, the sale of U.S. service stations, and the sale of the Downstream affiliates in Malaysia and Switzerland in 2012; from the sale of som properties and assets, and the sale of U.S. service stations in 2011; and from the sale of some Upstream Gulf of Mexico and other producing propertie m assets and investments and the formation of a Chemical joint venture in 2010. These gains are reported in \"Other income\" on the Consolidated Stat a cost company was redeemed. As part of the redemption, a variable note due in 2035 issued by Mobil Services (Bahamas) Ltd. was assigned to a con longer classified as third party long-term debt. This assignment did not result in a \"Reduction in long-term debt\" on the Statement of Cash Flows. et exchanges, primarily noncash transactions, of approximately $1 billion. This amount is not included in the \"Sales of subsidiaries, investments, and p perty, plant and equipment\" lines on the Statement of Cash Flows. iated with sales of subsidiaries, property, plant and equipment, and sales and returns of investments\" is a $3.6 billion deposit for an asset that was sold the outstanding equity of XTO Energy Inc. in an all-stock transaction valued at $24,659 million. 2012 2011 (millions of dollars) 555 557 24,349 27,254 h maturities of three months or less when acquired are classified gains from the Japan restructuring, the sale of an Upstream a and Switzerland in 2012; from the sale of some Upstream Gulf of Mexico and other producing properties, the sale of U.S. ed in \"Other income\" on the Consolidated Statement of Income. Services (Bahamas) Ltd. was assigned to a consolidated erm debt\" on the Statement of Cash Flows. n the \"Sales of subsidiaries, investments, and property, plant and a $3.6 billion deposit for an asset that was sold in 2012. 2010 ons of dollars) 703 18,941 Additional Working Capital Information Additional Working Capital Information [Abstract] Additional Working Capital Information 6. Additional Working Capital Information Notes and accounts receivable Notes and loans payable Accounts payable and accrued liabilities On December 31, 2012, unused credit lines for short-term financing totaled approxim December 31, 2012, and 2011, was 1.7 percent and 1.9 percent, respectively. 12 Months Ended Dec. 31, 2012 Information Trade, less reserves of $109 million and $128 million Other, less reserves of $36 million and $39 million Total Bank loans Commercial paper Long-term debt due within one year Other Total bilities Trade payables Payables to equity companies Accrued taxes other than income taxes Other Total redit lines for short-term financing totaled approximately $3.5 billion. Of this total, $3.0 billion supports commercial paper programs under terms neg as 1.7 percent and 1.9 percent, respectively. Dec. 31 Dec. 31 2012 2011 (millions of dollars) 28,373 30,044 6,614 8,598 34,987 38,642 663 1,963 1,025 1,237 2,281 3,431 2 762 3,653 7,711 33,789 6,114 4,130 33,969 5,553 7,123 6,695 10,422 50,728 57,067 per programs under terms negotiated when drawn. The weighted-average interest rate on short-term borrowings outstanding at Equity Company Information Equity Company Information [Abstract] Equity Company Information 7. Equity Company Information The summarized financial information below includes amounts related to certain less refining operations in North America; natural gas production, natural gas distribution chemical ventures. The Corporation's ownership in these ventures is in the form of sh company's analysis of the factors giving rise to the difference. The amortization of thi Equity Company Financial Summary Total revenues Income before income taxes Income taxes Current assets Long-term assets Current liabilities Long-term liabilities A list of significant equity companies as of December 31, 2012, together with the Cor Upstream Aera Energy LLC BEB Erdgas und Erdoel GmbH & Co. KG Cameroon Oil Transportation Company S.A. Castle Peak Power Company Limited Cross Timbers Energy, LLC Golden Pass LNG Terminal LLC Nederlandse Aardolie Maatschappij B.V. Qatar Liquefied Gas Company Limited Qatar Liquefied Gas Company Limited (2) Ras Laffan Liquefied Natural Gas Company Limited Ras Laffan Liquefied Natural Gas Company Limited (II) Ras Laffan Liquefied Natural Gas Company Limited (3) South Hook LNG Terminal Company Limited Tengizchevroil, LLP Terminale GNL Adriatico S.r.l. 12 Mont Dec. 3 on below includes amounts related to certain less-than-majority-owned companies and majority-owned subsidiaries where minority shareholders posse ; natural gas production, natural gas distribution and downstream operations in Europe; refining operations, petrochemical manufacturing, fuel sales a s ownership in these ventures is in the form of shares in corporate joint ventures as well as interests in partnerships. Differences between the company ing rise to the difference. The amortization of this difference, as appropriate, is included in \"income from equity affiliates.\" The share of total equity c Income from equity affiliates Total assets Net assets s as of December 31, 2012, together with the Corporation's percentage ownership interest, is detailed below: Percentage Ownership Interest 48 50 41 60 50 18 50 10 24 25 31 30 24 25 71 12 Months Ended Dec. 31, 2012 mpanies and majority-owned subsidiaries where minority shareholders possess the right to participate in significant management decisions (see Note 1) ns in Europe; refining operations, petrochemical manufacturing, fuel sales and power generation in Asia; crude production in Kazakhstan; and liquefie tures as well as interests in partnerships. Differences between the company's carrying value of an equity investment and its underlying equity in the ne e, is included in \"income from equity affiliates.\" The share of total equity company revenues from sales to ExxonMobil consolidated companies was 1 2012 ExxonMobil Total Share (millions of dollars) 224,953 69,411 67,572 20,882 20,703 5,868 48,708 15,014 59,612 18,483 111,131 33,798 170,743 49,698 52,281 14,265 68,855 19,715 52,190 18,301 ership interest, is detailed below: Percentage Ownership Interest Downstream Chalmette Refining, LLC 50 Fujian Refining & Petrochemical Co. Ltd. 25 Saudi Aramco Mobil Refinery Company Ltd. 50 TonenGeneral Sekiyu K.K. 22 Chemical Al-Jubail Petrochemical Company 50 Infineum Holdings B.V. 50 Saudi Yanbu Petrochemical Co. 50 management decisions (see Note 1). These companies are primarily engaged in crude production, natural gas production, natural gas marketing and duction in Kazakhstan; and liquefied natural gas (LNG) operations in Qatar. Also included are several refining, petrochemical manufacturing and nt and its underlying equity in the net assets of the affiliate are assigned to the extent practicable to specific assets and liabilities based on the Mobil consolidated companies was 16 percent, 19 percent and 18 percent in the years 2012, 2011 and 2010, respectively. 2011 2010 ExxonMobil Total Share ExxonMobil Total (millions of dollars) 204,635 68,908 65,147 20,892 153,020 48,075 19,812 5,603 13,962 49,096 15,289 34,113 52,879 17,317 48,573 96,908 30,833 90,646 149,787 41,016 48,150 12,454 139,219 33,160 62,472 18,728 59,596 46,299 16,968 46,463 , natural gas marketing and mical manufacturing and bilities based on the 010 ExxonMobil Share 48,355 14,735 4,058 10,677 15,860 29,805 45,665 10,260 17,976 17,429 12 Months Ended Dec. 31, 2012 Investments, Advances And Long-Term Receivables Investments, Advances And Long-Term Receivables [Abstract] Investments, Advances And Long-Term Receivables 8. Investments, Advances and Long-Term Receivables Companies carried at equity in underlying assets Investments Advances Companies carried at cost or less and stock investments carried at fair value Long-term receivables and miscellaneous investments at cost or less, net of reserves of $2,499 million and $469 million 12 Months Ended Dec. 31, 2012 ments, Advances and Long-Term Receivables Dec. 31, Dec. 31, 2012 2011 (millions of dollars) s carried at equity in underlying assets Investments Advances Total equity company investments and advances s carried at cost or less and stock investments carried at fair 18,530 16,968 9,959 9,740 28,489 26,708 437 1,544 m receivables and miscellaneous investments at cost or less, net s of $2,499 million and $469 million Total 5,792 6,081 34,718 34,333 Property, Plant And Equipment And Asset Retirement Obligations Property, Plant And Equipment And Asset Retirement Obligations [Abstract] Property, Plant And Equipment And Asset Retirement Obligations 9. Property, Plant and Equipment and Asset Retirement Obligations Property, Plant and Equipment Upstream Downstream Chemical Other In the Upstream segment, depreciation is generally on a unit-of-production basis, so station buildings and fixed improvements over a 20-year life. In the Chemical segme Accumulated depreciation and depletion totaled $182,365 million at the end of 2012 Asset Retirement Obligations The Corporation incurs retirement obligations for certain assets. The fair values of th factors as the existence of a legal obligation for an asset retirement obligation; techni measurements. The costs associated with these liabilities are capitalized as part of the Asset retirement obligations for downstream and chemical facilities generally becom based on plans for continued operations and as such, the fair value of the conditional The following table summarizes the activity in the liability for asset retirement obliga Beginning balance Ending balance 12 Months Ended Dec. 31, 2012 t and Equipment and Asset Retirement Obligations 31-Dec-12 and Equipment Cost 313,181 53,737 29,437 12,959 Total 409,314 egment, depreciation is generally on a unit-of-production basis, so depreciable life will vary by field. In the Downstream segment, investments in refin and fixed improvements over a 20-year life. In the Chemical segment, investments in process equipment are generally depreciated on a straight-line ba reciation and depletion totaled $182,365 million at the end of 2012 and $179,331 million at the end of 2011. Interest capitalized in 2012, 2011 and 201 t Obligations ncurs retirement obligations for certain assets. The fair values of these obligations are recorded as liabilities on a discounted basis, which is typically a tence of a legal obligation for an asset retirement obligation; technical assessments of the assets; estimated amounts and timing of settlements; discou he costs associated with these liabilities are capitalized as part of the related assets and depreciated as the reserves are produced. Over time, the liabilit obligations for downstream and chemical facilities generally become firm at the time the facilities are permanently shut down and dismantled. These o r continued operations and as such, the fair value of the conditional legal obligations cannot be measured, since it is impossible to estimate the future s le summarizes the activity in the liability for asset retirement obligations: 2012 (millions of dollars) e Accretion expense and other provisions Reduction due to property sales Payments made Liabilities incurred Foreign currency translation Revisions 10,578 709 -176 -816 163 290 1,225 11,973 12 Months Ended Dec. 31, 2012 31-Dec-12 31-Dec-11 Net Cost (millions of dollars) 181,795 23,053 14,085 283,710 67,900 30,405 8,016 11,980 226,949 393,995 e Downstream segment, investments in refinery and lubes basestock manufacturing facilities are generally depreciated on a straight-line basis over a 2 re generally depreciated on a straight-line basis over a 20-year life. 11. Interest capitalized in 2012, 2011 and 2010 was $506 million, $593 million and $532 million, respectively. es on a discounted basis, which is typically at the time the assets are installed. In the estimation of fair value, the Corporation uses assumptions and ju d amounts and timing of settlements; discount rates; and inflation rates. Asset retirement obligations incurred in the current period were Level 3 (unob eserves are produced. Over time, the liabilities are accreted for the change in their present value. manently shut down and dismantled. These obligations may include the costs of asset disposal and additional soil remediation. However, these sites ha since it is impossible to estimate the future settlement dates of such obligations. 2011 (millions of dollars) 9,614 581 -854 -662 117 -62 1,844 10,578 31-Dec-11 Net 163,975 28,801 14,469 7,419 214,664 preciated on a straight-line basis over a 25-year life and service . the Corporation uses assumptions and judgments regarding such in the current period were Level 3 (unobservable inputs) fair value soil remediation. However, these sites have indeterminate lives Accounting For Suspended Exploratory Well Costs Accounting For Suspended Exploratory Well Costs [Abstract] Accounting For Suspended Exploratory Well 10. Accounting for Suspended Exploratory Well Costs Costs The Corporation continues capitalization of exploratory well costs when the well has and the economic and operating viability of the project. The term \"project\" as used in for purposes of the rule may encompass numerous properties, agreements, investmen The following two tables provide details of the changes in the balance of suspended Change in capitalized suspended exploratory well costs: Balance beginning at January 1 Additions pending the determination of prove Charged to expense Reclassifications to wells, facilities and equip Divestments/Other Ending balance at December 31 Ending balance attributed to equity companies included above Period end capitalized suspended exploratory well costs: Capitalized for a period of one year or less Capitalized for a period of between one and f Capitalized for a period of between five and t Capitalized for a period of greater than ten ye Capitalized for a period greater than one year - subtotal Exploration activity often involves drilling multiple wells, over a number of years, to first capitalized well drilled in the preceding 12 months and those that have had expl Number of projects with first capitalized well drilled in the preceding 12 months Number of projects that have exploratory well costs capitalized for a period of greater than 12 months Of the 45 projects that have exploratory well costs capitalized for a period greater tha remaining 28 projects are those with completed exploratory activity progressing towa Country/Project (millions of dollars) Angola - Perpetua-Zina-Acacia Australia - East Pilchard - SE Longtom Indonesia - Natuna Kazakhstan - Kairan Malaysia - Besar - Bindu Nigeria - Bolia - Bosi - Bosi Central - Pegi - Usan South Strip - Other (5 projects) Norway - Gamma - H-North - Lavrans - Other (5 projects) Papua New Guinea - Juha United Kingdom - Phyllis United States - Tip Top Total 2012 (28 projects) 12 Months Ended Dec. 31, 2012 Well Costs xploratory well costs when the well has found a sufficient quantity of reserves to justify its completion as a producing well and the Corporation is mak he project. The term \"project\" as used in this report does not necessarily have the same meaning as under SEC Rule 13q-1 relating to government paym erous properties, agreements, investments, developments, phases, work efforts, activities, and components, each of which we may also informally desc he changes in the balance of suspended exploratory well costs as well as an aging summary of those costs. well costs: 2012 (millions of dollars) 2,881 868 -95 ions pending the determination of proved reserves ed to expense ssifications to wells, facilities and equipment based on the determination of proved reserves -631 tments/Other -344 2,679 s included above well costs: 3 2012 (millions of dollars) 866 1,176 401 alized for a period of between one and five years alized for a period of between five and ten years alized for a period of greater than ten years 236 - subtotal 1,813 Total 2,679 ultiple wells, over a number of years, to fully evaluate a project. The table below provides a numerical breakdown of the number of projects with susp 12 months and those that have had exploratory well costs capitalized for a period greater than 12 months. 2012 drilled in the preceding 12 months l costs capitalized for a period 10 ater than 12 months 45 Total 55 costs capitalized for a period greater than 12 months as of December 31, 2012, 17 projects have drilling in the preceding 12 months or exploratory act ed exploratory activity progressing toward development. The table below provides additional detail for those 28 projects, which total $557 million. ns of dollars) Years Dec. 31, Wells 2012 Drilled 15 2008 - 2009 10 2001 16 2010 118 1981 - 1983 53 2004 - 2007 18 1992 - 2010 2 1995 15 2002 - 2006 79 2002 - 2006 16 2006 32 2009 16 2011 16 2001 - 2002 21 2008 - 2009 16 2007 24 1995 - 1999 23 2008 - 2010 28 2007 8 2004 31 2009 557 completion as a producing well and the Corporation is making sufficient progress assessing the reserves ning as under SEC Rule 13q-1 relating to government payment reporting. For example, a single project nd components, each of which we may also informally describe as a \"project.\" of those costs. 2011 2010 2,893 310 -213 2,005 1,103 -104 -149 -136 (millions of dollars) 40 25 2,881 2,893 - - 2011 2010 310 1,922 409 1,103 1,294 278 240 218 2,571 1,790 (millions of dollars) 2,881 2,893 a numerical breakdown of the number of projects with suspended exploratory well costs which had their an 12 months. 2011 2010 4 9 58 59 62 68 have drilling in the preceding 12 months or exploratory activity planned in the next two years, while the al detail for those 28 projects, which total $557 million. Comment Oil field near Pazflor development, awaiting capacity in existing/planned infrastructure. Gas field near Kipper/Tuna development, awaiting capacity in existing/planned infrastructure. Gas field near Tuna development, awaiting capacity in existing/planned infrastructure. Development activity under way, while continuing discussions with the government on contract terms pursuant to executed Heads of Agreement. Evaluating commercialization and field development alternatives, while continuing discussions with the government regarding the development plan. Gas field off the east coast of Malaysia; progressing development plan. Awaiting capacity in existing/planned infrastructure. Evaluating development plan, while continuing discussions with the government regarding regional hub strategy. Development activity under way, while continuing discussions with the government regarding development plan. Development activity under way, while continuing discussions with the government regarding development plan. Awaiting capacity in existing/planned infrastructure. Evaluating development plans to tie into planned infrastructure. Evaluating and pursuing development of several additional discoveries. Evaluating development plan for tieback to existing production facilities. Progressing development and commercialization plans. Development awaiting capacity in existing Kristin production facility; evaluating development concepts for phased ullage scenarios. Evaluating development plans, including potential for tieback to existing production facilities. Working on development plans to tie into planned LNG facilities. Evaluating development plan for tieback to existing production facilities. Evaluating development concept and requisite facility upgrades. Leased Facilities Leased Facilities [Abstract] Leased Facilities 11. Leased Facilities At December 31, 2012, the Corporation and its consolidated subsidiaries held noncancelable operatin from noncancelable subleases is $111 million. Net rental cost under both cancelable and noncancelable operating leases incurred during 2012, 2011 Rental cost Less sublease rental income Net rental cost 12 Months Ended Dec. 31, 2012 ion and its consolidated subsidiaries held noncancelable operating charters and leases covering drilling equipment, tankers, service stations and other p 1 million. 2013 2014 2015 2016 2017 2018 and beyond Total and noncancelable operating leases incurred during 2012, 2011 and 2010 were as follows: 2012 (millions of dollars) 3,851 44 3,807 12 Months Ended Dec. 31, 2012 ment, tankers, service stations and other properties with minimum undiscounted lease commitments totaling $8,181 million as indicated in the table. E Related Lease Payments Sublease Under Minimum Rental Commitments Income (millions of dollars) 2,254 2,041 1,381 688 350 33 31 26 4 3 1,467 14 8,181 111 2011 2010 (millions of dollars) 4,061 3,762 74 90 3,987 3,672 tments totaling $8,181 million as indicated in the table. Estimated related rental income Related Sublease Rental Income 12 Months Ended Dec. 31, 2012 Earnings Per Share Earnings Per Share [Abstract] Earnings Per Share 12. Earnings Per Share 2012 Earnings per common share Net income attributable to ExxonMobil (millions of dollars) Weighted average number of common shares outstanding (millions of shares) Earnings per common share (dollars) 44,880 4,628 9.7 Earnings per common share - assuming dilution Net income attributable to ExxonMobil (millions of dollars) Weighted average number of common shares outstanding (millions of shares) Effect of employee stock-based awards Weighted average number of common shares outstanding - assuming dilution Earnings per common share - assuming dilution (dollars) Dividends paid per common share (dollars) 44,880 4,628 4,628 9.7 2.18 2011 2010 41,060 30,460 4,870 4,885 8.43 6.24 41,060 30,460 4,870 4,885 5 12 4,875 4,897 8.42 6.22 1.85 1.74 Financial Instruments And Derivatives Financial Instruments And Derivatives [Abstract] Financial Instruments And Derivatives 13. Financial Instruments and Derivatives Financial Instruments. The fair value of financial instruments is determined by refe value is notable is long-term debt. The estimated fair value of total long-term debt, in billion at December 31, 2012, and 2011, respectively. The fair value of long-term deb Long-term debt fair value The fair value hierarchy for long-term debt is primarily Level 1 and represents quoted determined through the use of present value and specific contract terms. Derivative Instruments. The Corporation's size, strong capital structure, geographic rates and commodity prices. As a result, the Corporation makes limited use of deriva leveraged features. When the Corporation does enter into derivative transactions, it is The estimated fair value of derivative instruments outstanding and recorded on the b in \"Other current assets\" or \"Accounts payable and accrued liabilities.\" The Corporation's fair value measurement of its derivative instruments use either Lev broker or other market-corroborated prices) inputs. The Corporation recognized a before-tax gain or (loss) related to derivative instrume and other operating revenue\" or \"Crude oil and product purchases.\" The Corporation believes there are no material market or credit risks to the Corporati 12 Months Ended Dec. 31, 2012 ivatives ue of financial instruments is determined by reference to observable market data and other valuation techniques as appropriate. The only category of fi he estimated fair value of total long-term debt, including capitalized lease obligations, was $8.5 billion and $9.8 billion at December 31, 2012, and 201 011, respectively. The fair value of long-term debt by hierarchy level at December 31, 2012 is shown below: As of December 31, 2012 Level 1 Level 2 (millions of dollars) 6,482 1,480 m debt is primarily Level 1 and represents quoted prices in active markets. Level 2 includes debt whose fair value is based upon a publicly available in t value and specific contract terms. ration's size, strong capital structure, geographic diversity and the complementary nature of the Upstream, Downstream and Chemical businesses redu ult, the Corporation makes limited use of derivatives to mitigate the impact of such changes. The Corporation does not engage in speculative derivativ ation does enter into derivative transactions, it is to offset exposures associated with interest rates, foreign currency exchange rates and hydrocarbon p e instruments outstanding and recorded on the balance sheet was a net asset of $2 million at year-end 2012 and a net liability of $3 million at year-end ts payable and accrued liabilities.\" ment of its derivative instruments use either Level 1 (observable quoted prices on active exchanges) or Level 2 (derivatives that are determined by eit prices) inputs. -tax gain or (loss) related to derivative instruments of $(23) million, $131 million and $221 million during 2012, 2011 and 2010, respectively. Income ude oil and product purchases.\" o material market or credit risks to the Corporation's financial position, results of operations or liquidity as a result of the derivative activities describe Months Ended ec. 31, 2012 luation techniques as appropriate. The only category of financial instruments where the difference between fair value and recorded book .5 billion and $9.8 billion at December 31, 2012, and 2011, respectively, as compared to recorded book values of $7.9 billion and $9.3 shown below: As of December 31, 2012 Level 3 (millions of dollars) 496 ebt whose fair value is based upon a publicly available index. The Level 3 amount is primarily capitalized leases whose value is typically he Upstream, Downstream and Chemical businesses reduce the Corporation's enterprise-wide risk from changes in interest rates, currency The Corporation does not engage in speculative derivative activities or derivative trading activities nor does it use derivatives with rates, foreign currency exchange rates and hydrocarbon prices that arise from existing assets, liabilities and forecasted transactions. ear-end 2012 and a net liability of $3 million at year-end 2011. Assets and liabilities associated with derivatives are usually recorded either hanges) or Level 2 (derivatives that are determined by either market prices on an active market for similar assets or by prices quoted by a million during 2012, 2011 and 2010, respectively. Income statement effects associated with derivatives are usually recorded either in \"Sales or liquidity as a result of the derivative activities described above. n fair value and recorded book alues of $7.9 billion and $9.3 Total 8,458 d leases whose value is typically hanges in interest rates, currency oes it use derivatives with d forecasted transactions. vatives are usually recorded either assets or by prices quoted by a e usually recorded either in \"Sales Long-Term Debt Long-Term Debt [Abstract] Long-Term Debt 14. Long-Term Debt At December 31, 2012, long-term debt consisted of $7,325 million due in U.S. dollars and $603 milli and is included in current liabilities. The amounts of long-term debt maturing in each of the four year Summarized long-term debt at year-end 2012 and 2011 are shown in the table below: XTO Energy Inc. (1) Mobil Services (Bahamas) Ltd. Mobil Producing Nigeria Unlimited (4) Esso (Thailand) Public Company Ltd. (5) Mobil Corporation Industrial revenue bonds due 2014-2051 (6) Other U.S. dollar obligations (7) Other foreign currency obligations Capitalized lease obligations (8) (1) (2) (3) Includes premiums of $326 million. Average effective interest rate of 0.2% in 2011. Average effective interest rate of 0.5% in 2012 and 0.3% in 2011. (4) (5) (6) (7) (8) Average effective interest rate of 4.6% in 2012 and 4.2% in 2011. Average effective interest rate of 3.5% in 2012 and 3.2% in 2011. Average effective interest rate of 0.1% in 2012 and 0.1% in 2011. Average effective interest rate of 2.7% in 2012 and 4.8% in 2011. Average imputed interest rate of 7.6% in 2012 and 8.5% in 2011. 12 Months Ended Dec. 31, 2012 ion due in U.S. dollars and $603 million representing the U.S. dollar equivalent at year-end exchange rates of amounts payable in foreign currencies. T debt maturing in each of the four years after December 31, 2013, in millions of dollars, are: 2014 - $907; 2015 - $710; 2016 - $454; and 2017 - $814 wn in the table below: 6.250% senior note due 2013 4.625% senior note due 2013 5.750% senior note due 2013 4.900% senior note due 2014 5.000% senior note due 2015 5.300% senior note due 2015 5.650% senior note due 2016 6.250% senior note due 2017 5.500% senior note due 2018 6.500% senior note due 2018 6.100% senior note due 2036 6.750% senior note due 2037 6.375% senior note due 2038 s) Ltd. Variable note due 2035 (2) Variable note due 2034 (3) a Unlimited (4) Variable notes due 2013-2019 Company Ltd. (5) Variable notes due 2014-2017 8.625% debentures due 2021 due 2014-2051 (6) ions (7) bligations ions (8) % in 2011. Total long-term debt % in 2011. % in 2011. % in 2011. % in 2011. in 2011. 2 Months Ended Dec. 31, 2012 nd exchange rates of amounts payable in foreign currencies. These amounts exclude that portion of long-term debt, totaling $1,025 million, which mat e: 2014 - $907; 2015 - $710; 2016 - $454; and 2017 - $814. At December 31, 2012, the Corporation's unused long-term credit lines were not materia 2012 2011 (millions of dollars) 254 135 249 217 501 396 495 201 314 240 185 145 346 260 138 255 222 513 402 506 203 317 241 311 972 311 751 543 414 413 249 248 2,690 74 6 2,315 496 31 431 260 7,928 9,322 ling $1,025 million, which matures within one year rm credit lines were not material. 12 Months Ended Dec. 31, 2012 Incentive Program Incentive Program [Abstract] Incentive Program 15. Incentive Program The 2003 Incentive Program provides for grants of stock options, stock appreciation rights (SARs) employees of the Corporation and those affiliates at least 50 percent owned. Outstanding awards a instrument. Options and SARs may be granted at prices not less than 100 percent of market value number of shares of stock that may be issued under the 2003 Incentive Program is 220 million. Aw maximum limit. The 2003 Incentive Program does not have a specified term. New awards may be plan early. At the end of 2012, remaining shares available for award under the 2003 Incentive Prog Restricted Stock. Awards totaling 10,017 thousand, 10,533 thousand, and 10,648 thousand (exclu restricted (nonvested) common stock units were granted in 2012, 2011 and 2010, respectively. Com date of grant and is recognized in income over the requisite service period. These shares are issued recorded as liabilities and their changes in fair value are recognized over the vesting period. Durin and are subject to forfeiture. The majority of the awards have graded vesting periods, with 50 perc percent vesting after seven years. Awards granted to a small number of senior executives have vest retirement, whichever occurs later, for the remaining 50 percent of the award. Additionally, in 2010 long-term incentive awards totaling 4,206 thousand shares of restricted (non association with the XTO merger. The majority of these awards vest over periods of up to three ye The Corporation has purchased shares in the open market and through negotiated transactions to o may be discontinued at any time without prior notice. The following tables summarize information about restricted stock and restricted stock units for th Restricted stock and units outstanding Shares (thousands) Issued and outstanding at January 1 2011 award issued in 2012 Vested Forfeited Issued and outstanding at December 31 46,781 10,522 -10,537 -315 46,451 Value of restricted stock and units Grant price (dollars) Value at date of grant: Restricted stock and units settled in stock Merger-related granted and converted XTO awards Units settled in cash Total value As of December 31, 2012, there was $2,179 million of unrecognized compensation cost related to weighted-average period of 4.5 years. The compensation cost charged against income for the restri million for 2012, 2011 and 2010, respectively. The income tax benefit recognized in income relate for the same periods, respectively. The fair value of shares and units vested in 2012, 2011 and 201 payments of $66 million, $46 million and $42 million for vested restricted stock units settled in ca Stock Options. The Corporation has not granted any stock options under the 2003 Incentive Progr the end of 2011. In 2010, the Corporation granted 12,393 thousand of converted XTO stock option These stock options generally vest and become exercisable ratably over a three-year period, and m reaches specified levels. Some stock option tranches vest only when the common stock price reach exercise price of $78.60, outstanding at December 31, 2012. Cash received from stock option exercises was $193 million, $924 million and $1,043 million for options exercised was $54 million, $221 million and $89 million for 2012, 2011 and 2010, respect and 2010 was $79 million, $986 million and $539 million, respectively. 12 Months Ended Dec. 31, 2012 ptions, stock appreciation rights (SARs), restricted stock and other forms of award. Awards may be granted to eligible 0 percent owned. Outstanding awards are subject to certain forfeiture provisions contained in the program or award t less than 100 percent of market value on the date of grant and have a maximum life of 10 years. The maximum 03 Incentive Program is 220 million. Awards that are forfeited, expire or are settled in cash, do not count against this e a specified term. New awards may be made until the available shares are depleted, unless the Board terminates the or award under the 2003 Incentive Program were 124,736 thousand. 3 thousand, and 10,648 thousand (excluding XTO merger-related grants) of restricted (nonvested) common stock and 2012, 2011 and 2010, respectively. Compensation expense for these awards is based on the price of the stock at the e service period. These shares are issued to employees from treasury stock. The units that are settled in cash are cognized over the vesting period. During the applicable restricted periods, the shares may not be sold or transferred ve graded vesting periods, with 50 percent of the shares in each award vesting after three years and the remaining 50 l number of senior executives have vesting periods of five years for 50 percent of the award and of 10 years or rcent of the award. 4,206 thousand shares of restricted (nonvested) common stock, with a value of $250 million, were granted in wards vest over periods of up to three years after the initial grant. and through negotiated transactions to offset shares issued in conjunction with benefit plans and programs. Purchases ed stock and restricted stock units for the year ended December 31, 2012. 2012 Weighted Average Grant-Date