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Description of Business and Summary of Significant Accounting Policies | 12 Months Ended
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Dec. 31, 2013
Description of Business and Summary of Significant Accounting Policies |
1. | Description of Business and Summary of Significant Accounting Policies
A description of the business and basis of presentation follows: Description of business — Patterson-UTI Energy, Inc., through its wholly-owned subsidiaries (collectively referred to herein as “Patterson-UTI” or the “Company”), provides onshore contract drilling services to major and independent oil and natural gas operators in the continental United States, Alaska and western and northern Canada. The Company provides pressure pumping services to oil and natural gas operators primarily in Texas and the Appalachian region. The Company also invests in oil and natural gas properties on a non-operating working interest basis. Basis of presentation — The consolidated financial statements include the accounts of Patterson-UTI and its wholly-owned subsidiaries. All significant intercompany accounts and transactions have been eliminated. Except for wholly-owned subsidiaries, the Company has no controlling financial interests in any other entity which would require consolidation. The U.S. dollar is the functional currency for all of the Company’s operations except for its Canadian operations, which use the Canadian dollar as its functional currency. The effects of exchange rate changes are reflected in accumulated other comprehensive income, which is a separate component of stockholders’ equity. A summary of the significant accounting policies follows: Management estimates — The preparation of financial statements in conformity with accounting principles generally accepted in the United States of America requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from such estimates. Revenue recognition — Revenues from daywork drilling and pressure pumping activities are recognized as services are performed. Expenditures reimbursed by customers are recognized as revenue and the related expenses are recognized as direct costs. All of the wells the Company drilled in 2013, 2012 and 2011 were drilled under daywork contracts. Accounts receivable — Trade accounts receivable are recorded at the invoiced amount. The allowance for doubtful accounts represents the Company’s estimate of the amount of probable credit losses existing in the Company’s accounts receivable. The Company reviews the adequacy of its allowance for doubtful accounts at least quarterly. Significant individual accounts receivable balances and balances which have been outstanding greater than 90 days are reviewed individually for collectability. Account balances, when determined to be uncollectable, are charged against the allowance. Inventories — Inventories consist primarily of sand and other products to be used in conjunction with the Company’s pressure pumping activities. The inventories are stated at the lower of cost or market, determined by the first-in, first-out method. Property and equipment — Property and equipment is carried at cost less accumulated depreciation. Depreciation is provided on the straight-line method over the estimated useful lives. The method of depreciation does not change whenever equipment becomes idle. The estimated useful lives, in years, are shown below:
|  | Useful Lives |
Drilling rigs and other equipment |  |  | 1.25-15 |
Buildings |  |  | 15-20 |
Other |  |  | 3-12 |
Long-lived assets, including property and equipment, are evaluated for impairment when certain triggering events or changes in circumstances indicate that the carrying values may not be recoverable over their estimated remaining useful life. Oil and natural gas properties — Working interests in oil and natural gas properties are accounted for using the successful efforts method of accounting. Under the successful efforts method of accounting, exploration costs which result in the discovery of oil and natural gas reserves and all development costs are capitalized to the appropriate well. Exploration costs which do not result in discovering oil and natural gas reserves are charged to expense when such determination is made. Costs of exploratory wells are initially capitalized to wells-in-progress until the outcome of the drilling is known. The Company reviews wells-in-progress quarterly to determine whether sufficient progress is being made in assessing the reserves and economic viability of the respective projects. If no progress has been made in assessing the reserves and economic viability of a project after one year following the completion of drilling, the Company considers the well costs to be impaired and recognizes the costs as expense. Geological and geophysical costs, including seismic costs, and costs to carry and retain undeveloped properties are charged to expense when incurred. The capitalized costs of both developmental and successful exploratory type wells, consisting of lease and well equipment and intangible development costs, are depreciated, depleted and amortized using the units-of-production method, based on engineering estimates of total proved developed oil and natural gas reserves for each respective field. Oil and natural gas leasehold acquisition costs are depreciated, depleted and amortized using the units-of-production method, based on engineering estimates of total proved oil and natural gas reserves for each respective field. The Company reviews its proved oil and natural gas properties for impairment whenever a triggering event occurs, such as downward revisions in reserve estimates or decreases in expected future oil and natural gas prices. Proved properties are grouped by field and undiscounted cash flow estimates are prepared based on management’s expectation of future pricing over the lives of the respective fields. These cash flow estimates are reviewed by an independent petroleum engineer. If the net book value of a field exceeds its undiscounted cash flow estimate, impairment expense is measured and recognized as the difference between net book value and fair value. The fair value estimates used in measuring impairment are based on management’s expectations of future commodity prices over the life of the respective field and the net future cash inflows from developing and operating these fields. The Company reviews unproved oil and natural gas properties quarterly to assess potential impairment. The Company’s impairment assessment is made on a lease-by-lease basis and considers factors such as management’s intent to drill, lease terms and abandonment of an area. If an unproved property is determined to be impaired, the related property costs are expensed. Goodwill — Goodwill is considered to have an indefinite useful economic life and is not amortized. The Company assesses impairment of its goodwill at least annually as of December 31, or on an interim basis if events or circumstances indicate that the fair value of goodwill may have decreased below its carrying value. Maintenance and repairs — Maintenance and repairs are charged to expense when incurred. Renewals and betterments which extend the life or improve existing property and equipment are capitalized. Disposals — Upon disposition of property and equipment, the cost and related accumulated depreciation are removed and any resulting gain or loss is reflected in the consolidated statement of operations. Net income per common share — The Company provides a dual presentation of its net income per common share in its consolidated statements of operations: Basic net income per common share (“Basic EPS”) and diluted net income per common share (“Diluted EPS”). Basic EPS excludes dilution and is computed by first allocating earnings between common stockholders and holders of non-vested shares of restricted stock. Basic EPS is then determined by dividing the earnings attributable to common stockholders by the weighted average number of common shares outstanding during the period, excluding non-vested shares of restricted stock. Diluted EPS is based on the weighted average number of common shares outstanding plus the dilutive effect of potential common shares, including stock options, non-vested shares of restricted stock and restricted stock units. The dilutive effect of stock options and restricted stock units is determined using the treasury stock method. The dilutive effect of non-vested shares of restricted stock is based on the more dilutive of the treasury stock method or the two-class method, assuming a reallocation of undistributed earnings to common stockholders after considering the dilutive effect of potential common shares other than non-vested shares of restricted stock. The following table presents information necessary to calculate income from continuing operations per share, loss from discontinued operations per share and net income per share for the years ended December 31, 2013, 2012 and 2011, as well as potentially dilutive securities excluded from the weighted average number of diluted common shares outstanding because their inclusion would have been anti-dilutive (in thousands, except per share amounts):
|  | 2013 |  |  | 2012 |  |  | 2011 |
BASIC EPS: |  |  |  |  |  |  |  |  |  |  |  |
Income from continuing operations |  | $ | 188,009 |  |  | $ | 299,477 |  |  | $ | 322,780 |
Adjust for income attributed to holders of non-vested restricted stock |  |  | (1,859 | ) |  |  | (2,532 | ) |  |  | (2,545 | )
Income from continuing operations attributed to common stockholders |  | $ | 186,150 |  |  | $ | 296,945 |  |  | $ | 320,235 |
Loss from discontinued operations, net |  | $ | — |  |  | $ | — |  |  | $ | (367 | )
Adjust for loss attributed to holders of non-vested restricted stock |  |  | — |  |  |  | — |  |  |  | 3 |
Loss from discontinued operations attributed to common stockholders |  | $ | — |  |  | $ | — |  |  | $ | (364 | )
Weighted average number of common shares outstanding, excluding non-vested shares of restricted stock |  |  | 144,356 |  |  |  | 151,144 |  |  |  | 153,871 |
Basic income from continuing operations per common share |  | $ | 1.29 |  |  | $ | 1.96 |  |  | $ | 2.08 |
Basic loss from discontinued operations per common share |  | $ | 0.00 |  |  | $ | 0.00 |  |  | $ | 0.00 |
Basic net income per common share |  | $ | 1.29 |  |  | $ | 1.96 |  |  | $ | 2.08 |
DILUTED EPS: |  |  |  |  |  |  |  |  |  |  |  |
Income from continuing operations attributed to common stockholders |  | $ | 186,150 |  |  | $ | 296,945 |  |  | $ | 320,235 |
Weighted average number of common shares outstanding, excluding non-vested shares of restricted stock |  |  | 144,356 |  |  |  | 151,144 |  |  |  | 153,871 |
Add dilutive effect of potential common shares |  |  | 947 |  |  |  | 555 |  |  |  | 1,433 |
Weighted average number of diluted common shares outstanding |  |  | 145,303 |  |  |  | 151,699 |  |  |  | 155,304 |
Diluted income from continuing operations per common share |  | $ | 1.28 |  |  | $ | 1.96 |  |  | $ | 2.06 |
Diluted loss from discontinued operations per common share |  | $ | 0.00 |  |  | $ | 0.00 |  |  | $ | 0.00 |
Diluted net income per common share |  | $ | 1.28 |  |  | $ | 1.96 |  |  | $ | 2.06 |
Potentially dilutive securities excluded as anti-dilutive |  |  | 2,447 |  |  |  | 5,416 |  |  |  | 1,641 |
Income taxes — The asset and liability method is used in accounting for income taxes. Under this method, deferred tax assets and liabilities are recognized for operating loss and tax credit carryforwards and for the future tax consequences attributable to differences between the financial statement carrying amounts of existing assets and liabilities and their respective tax bases. Deferred tax assets and liabilities are measured using enacted tax rates expected to apply to taxable income in the year in which those temporary differences are expected to be recovered or settled. The effect on deferred tax assets and liabilities of a change in tax rates is recognized in the results of operations in the period that includes the enactment date. If applicable, a valuation allowance is recorded to reduce the carrying amounts of deferred tax assets unless it is more likely than not that such assets will be realized. The Company’s policy is to account for interest and penalties with respect to income taxes as operating expenses. Stock-based compensation — The Company recognizes the cost of share-based payments under the fair-value-based method. Under this method, compensation cost related to share-based payments is measured based on the estimated fair value of the awards at the date of grant, net of estimated forfeitures. This expense is recognized over the expected life of the awards (See Note 10). Statement of cash flows — For purposes of reporting cash flows, cash and cash equivalents include cash on deposit and money market funds. Recently Issued Accounting Standards — In February 2013, the FASB issued an accounting standards update that requires additional disclosures regarding reclassifications out of accumulated other comprehensive income. This requirement is effective for fiscal years, and interim periods within those years, beginning after December 15, 2012, and became effective for the Company in the quarter ended March 31, 2013. The adoption of this update did not have a material impact on the Company’s disclosures included in its consolidated financial statements. The Company includes in accumulated other comprehensive income the cumulative translation adjustment of its foreign subsidiary. In February 2013, the FASB issued an accounting standards update to provide guidance for the recognition, measurement, and disclosure of obligations resulting from joint and several liability arrangements for which the total amount of the obligation within the scope of the update is fixed at the reporting date, except for obligations addressed within existing guidance in U.S. GAAP. The guidance requires an entity to measure those obligations as the sum of the amount the reporting entity agreed to pay on the basis of its arrangement among its co-obligors and any additional amount the reporting entity expects to pay on behalf of its co-obligors. The update also requires an entity to disclose the nature and amount of the obligation as well as other information about those obligations. The requirements in this update are effective during interim and annual periods beginning after December 15, 2013. The adoption of this update is not expected to have a material impact on the Company’s consolidated financial statements.

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- Definition The entire disclosure for the general note to the financial statements for the reporting entity which may include, descriptions of the basis of presentation, business description, significant accounting policies, consolidations, reclassifications, new pronouncements not yet adopted and changes in accounting principles. + References No definition available. + Details
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