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Description Of The Business And Summary Of Significant Accounting Policies (Policies) | 12 Months Ended
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Dec. 31, 2015
Description Of The Business And Summary Of Significant Accounting Policies [Abstract] |
Business | Business We are one of the leading providers of offshore contract drilling services to the international oil and gas industry. We own and operate an offshore drilling rig fleet of 64 rigs spanning most of the strategic markets around the globe. Our rig fleet includes ten drillships, 13 dynamically positioned semisubmersible rigs, three moored semisubmersible rigs and 42 jackup rigs, including four rigs under construction. Our fleet is the world's second largest amongst competitive rigs, our ultra-deepwater fleet is one of the newest in the industry, and our premium jackup fleet is the largest of any offshore drilling company. Our customers include many of the leading national and international oil companies, in addition to many independent operators. We are among the most geographically diverse offshore drilling companies, with current operations spanning approximately 15 countries on six continents. The markets in which we operate include the U.S. Gulf of Mexico, Mexico, Brazil, the Mediterranean, the North Sea, the Middle East, West Africa, Australia and Southeast Asia. We provide drilling services on a "day rate" contract basis. Under day rate contracts, we provide a drilling rig and rig crews and receive a fixed amount per day for each day we are performing drilling or related services. Our customers bear substantially all of the costs of constructing the well and supporting drilling operations, as well as the economic risk relative to the success of the well. In addition, our customers may pay all or a portion of the cost of moving our equipment and personnel to and from the well site.
Redomestication | Redomestication During 2009, we completed a reorganization of the corporate structure of the group of companies controlled by our predecessor, ENSCO International Incorporated ("Ensco Delaware"), pursuant to which an indirect, wholly-owned subsidiary merged with Ensco Delaware, and Ensco plc became our publicly-held parent company incorporated under English law (the "redomestication"). We remain subject to the U.S. Securities and Exchange Commission (the "SEC") reporting requirements, the mandates of the Sarbanes-Oxley Act of 2002, as amended, and the applicable corporate governance rules of the New York Stock Exchange ("NYSE"), and we continue to report our consolidated financial results in U.S. dollars and in accordance with U.S. generally accepted accounting principles ("U.S. GAAP"). We also comply with additional reporting requirements of English law.
Basis Of Presentation-U.K. Companies Act 2006 Section 435 Statement | Basis of Presentation—U.K. Companies Act 2006 Section 435 Statement The accompanying consolidated financial statements have been prepared in accordance with U.S. GAAP, which the Board of Directors consider to be the most meaningful presentation of our results of operations and financial position. The accompanying consolidated financial statements do not constitute statutory accounts required by the U.K. Companies Act 2006, which will be prepared in accordance with Financial Reporting Standard 102 The Financial Reporting Standard applicable in the UK and Republic of Ireland (“FRS 102”) as issued in August 2014. An explanation of how the transition to FRS 102 has affected financial position and financial performance of the Group will be provided in those statements, which will be delivered to the Registrar of Companies in the U.K. following the annual general meeting of shareholders. The U.K. statutory accounts are expected to include an unqualified auditor’s report, which is not expected to contain any references to matters on which the auditors drew attention by way of emphasis without qualifying the report or any statements under Sections 498(2) or 498(3) of the U.K. Companies Act 2006.
Principles Of Consolidation | Principles of Consolidation The accompanying consolidated financial statements include the accounts of Ensco plc and its majority-owned subsidiaries. All significant intercompany accounts and transactions have been eliminated. Certain previously reported amounts have been reclassified to conform to the current year presentation.
Cash Equivalents And Short-Term Investments | Cash Equivalents and Short-Term Investments Highly liquid investments with maturities of three months or less at the date of purchase are considered cash equivalents. Highly liquid investments with maturities of greater than three months but less than one year at the date of purchase are classified as short-term investments. Short-term investments, consisting of time deposits with initial maturities in excess of three months but less than one year, were included in other current assets on our consolidated balance sheets and totaled $1.2 billion and $757.3 million as of December 31, 2015 and 2014, respectively. Cash flows from purchases and maturities of short-term investments were classified as investing activities in our consolidated statements of cash flows for the years ended December 31, 2015, 2014 and 2013. To mitigate our credit risk, our investments in time deposits are diversified across multiple, high-quality financial institutions.
Pervasiveness Of Estimates | Pervasiveness of Estimates The preparation of financial statements in conformity with U.S. GAAP requires us to make certain estimates, judgments and assumptions that affect the reported amounts of assets and liabilities, the related revenues and expenses and disclosures of gain and loss contingencies as of the date of the financial statements. Actual results could differ from those estimates.
Foreign Currency Remeasurement And Translation | Foreign Currency Remeasurement and Translation Our functional currency is the U.S. dollar. As is customary in the oil and gas industry, a majority of our revenues and expenses are denominated in U.S. dollars; however, a portion of the revenues earned and expenses incurred by certain of our subsidiaries are denominated in currencies other than the U.S. dollar ("foreign currencies"). These transactions are remeasured in U.S. dollars based on a combination of both current and historical exchange rates. Most transaction gains and losses, including certain gains and losses on our derivative instruments, are included in other, net, in our consolidated statement of operations. Certain gains and losses from the translation of foreign currency balances of our non-U.S. dollar functional currency subsidiaries are included in accumulated other comprehensive income on our consolidated balance sheet. Net foreign currency exchange gains and losses, inclusive of offsetting fair value derivatives, were $5.4 million of gains, $2.6 million of losses and $6.4 million of gains, and were included in other, net, in our consolidated statements of operations for the years ended December 31, 2015, 2014 and 2013, respectively.
Property And Equipment | Property and Equipment All costs incurred in connection with the acquisition, construction, major enhancement and improvement of assets are capitalized, including allocations of interest incurred during periods that our drilling rigs are under construction or undergoing major enhancements and improvements. Repair and maintenance costs are charged to contract drilling expense in the period in which they are incurred. Upon sale or retirement of assets, the related cost and accumulated depreciation are removed from the balance sheet, and the resulting gain or loss is included in contract drilling expense, unless reclassified to discontinued operations. Our property and equipment is depreciated on a straight-line basis, after allowing for salvage values, over the estimated useful lives of our assets. Drilling rigs and related equipment are depreciated over estimated useful lives ranging from four to 35 years. Buildings and improvements are depreciated over estimated useful lives ranging from two to 30 years. Other equipment, including computer and communications hardware and software costs, is depreciated over estimated useful lives ranging from three to six years. On December 31, 2015, we evaluated our current judgments and assumptions used in determining the useful lives of our drilling rigs. We considered both historical experience and expectations of future operations, utilization and performance of our assets based on recent changes in the current market environment. As a result, we reduced the useful lives of certain floaters and jackups effective January 1, 2016. We estimate this reduction in useful lives will increase depreciation expense by approximately $20.0 million for the year ended December 31, 2016. We evaluate the carrying value of our property and equipment for impairment when events or changes in circumstances indicate that the carrying value of such assets may not be recoverable. For property and equipment used in our operations, recoverability generally is determined by comparing the carrying value of an asset to the expected undiscounted future cash flows of the asset. If the carrying value of an asset is not recoverable, the amount of impairment loss is measured as the difference between the carrying value of the asset and its estimated fair value. Property and equipment held-for-sale is recorded at the lower of net book value or net realizable value. During 2015, we recorded a pre-tax, non cash loss on impairment of long-lived assets of $2.6 billion, of which $2.5 billion related to our long-lived assets held-for-use. See "Note 3 - Property and Equipment" for additional information on these impairments. We estimate the impairment charge on our held-for-use assets will cause a decline in depreciation expense of approximately $170 million for the year ended December 31, 2016. If the global economy deteriorates and/or our expectation relative to future offshore drilling industry conditions decline, it is reasonably possible that additional impairment charges may occur with respect to specific individual rigs, groups of rigs, such as a specific type of drilling rig, or rigs in a certain geographic location.
Goodwill | Goodwill Our business consists of three operating segments: (1) Floaters, which includes our drillships and semisubmersible rigs, (2) Jackups and (3) Other, which consists of management services on rigs owned by third-parties. Our two reportable segments, Floaters and Jackups, represent our reporting units. We test goodwill for impairment on an annual basis as of December 31 or when events or changes in circumstances indicate that a potential impairment exists. When testing goodwill for impairment, we first consider whether or not to assess qualitative factors to determine whether the existence of events or circumstances lead to a determination that is more-likely-than-not that the fair value of a reporting unit is less than its carrying amount. If we conclude that the fair value of one or both of our reporting units has more-likely-than-not declined below its carrying amount after qualitatively assessing existing facts and circumstances, or, alternatively, if we elect to forgo the qualitative assessment, we perform a quantitative assessment whereby we estimate the fair value of each reporting unit. In most instances, our calculation of the fair value of our reporting units is based on estimates of future discounted cash flows to be generated by the drilling rigs in the reporting unit. As of December 31, 2015, given the deterioration in forecasted day rates and utilization, the sustained decline in our stock price and the impairment charge on certain rigs during the fourth quarter, we elected to forgo the qualitative assessment and performed a quantitative assessment on both reporting units. As a result of the quantitative assessment, we concluded that our Floater and Jackup reporting units' goodwill balances were impaired. We recorded a non-cash loss on impairment of $192.6 million and $83.5 million for the Jackups and Floaters reporting units, respectively, which was included in loss on impairment in our consolidated statement of operations for the year ended December 31, 2015. There is no remaining goodwill on our consolidated balance sheet as of December 31, 2015. See "Note 8 - Goodwill and Other Intangible Assets and Liabilities" for additional information on our goodwill.
Operating Revenues And Expenses | Operating Revenues and Expenses Our drilling contracts ("contracts") are performed on a day rate basis, and the terms of such contracts are typically for a specific period of time or the period of time required to complete a specific task, such as drill a well. Contract revenues and expenses are recognized on a per day basis, as the work is performed. Day rate revenues are typically earned, and contract drilling expense is typically incurred, on a uniform basis over the terms of our contracts. In connection with some contracts, we receive lump-sum fees or similar compensation for the mobilization of equipment and personnel prior to the commencement of drilling services or the demobilization of equipment and personnel upon contract completion. Fees received for the mobilization or demobilization of equipment and personnel are included in operating revenues. The costs incurred in connection with the mobilization and demobilization of equipment and personnel are included in contract drilling expense. Mobilization fees received and costs incurred prior to commencement of drilling operations are deferred and recognized on a straight-line basis over the period that the related drilling services are performed. Demobilization fees and related costs are recognized as incurred upon contract completion. Costs associated with the mobilization of equipment and personnel to more promising market areas without contracts are expensed as incurred. Deferred mobilization costs were included in other current assets and other assets, net, on our consolidated balance sheets and totaled $77.0 million and $95.7 million as of December 31, 2015 and 2014, respectively. Deferred mobilization revenue was included in accrued liabilities and other, and other liabilities on our consolidated balance sheets and totaled $111.8 million and $149.4 million as of December 31, 2015 and 2014, respectively. In connection with some contracts, we receive up-front lump-sum fees or similar compensation for capital improvements to our drilling rigs. Such compensation is deferred and recognized as revenue over the period that the related drilling services are performed, and the cost is capitalized and depreciated over the useful life of the asset. Deferred revenue associated with capital improvements was included in accrued liabilities and other, and other liabilities on our consolidated balance sheets and totaled $287.2 million and $428.9 million as of December 31, 2015 and 2014, respectively. We may receive termination fees if certain drilling contracts are terminated by the customer prior to the end of the contractual term. Such compensation is recognized as revenues when services have been completed under the terms of the contract, the termination fee can be reasonably measured and collectability is reasonably assured. For the year ended December 31, 2015, operating revenues included $110.6 million for the ENSCO DS-4 lump sum termination fee, which we collected in October, as well as $98.3 million related to the ENSCO DS-9 termination, which included an $18.4 million lump-sum fee for mobilization, capital upgrades and day rate revenue earned during initial acceptance testing. Under the terms of the ENSCO DS-9 contract, our customer is obligated to pay us monthly termination fees for a period of two years equal to the operating day rate (approximately $550,000), which will be reduced pursuant to our obligation to mitigate idle rig costs, such as manning and maintenance activity, while the rig is idle and without a contract. We are in discussions with our customer on the amount of this reduction. The day rate may also be adjusted if we recontract the rig. We must obtain certifications from various regulatory bodies in order to operate our drilling rigs and must maintain such certifications through periodic inspections and surveys. The costs incurred in connection with maintaining such certifications, including inspections, tests, surveys and drydock, as well as remedial structural work and other compliance costs, are deferred and amortized over the corresponding certification periods. Deferred regulatory certification and compliance costs were included in other current assets and other assets, net, on our consolidated balance sheets and totaled $21.2 million and $20.0 million as of December 31, 2015 and 2014, respectively. In certain countries in which we operate, taxes such as sales, use, value-added, gross receipts and excise may be assessed by the local government on our revenues. We generally record our tax-assessed revenue transactions on a net basis in our consolidated statement of operations.
Derivative Instruments | Derivative Instruments We use derivatives to reduce our exposure to various market risks, primarily foreign currency exchange rate risk. See "Note 5 - Derivative Instruments" for additional information on how and why we use derivatives. All derivatives are recorded on our consolidated balance sheet at fair value. Derivatives subject to legally enforceable master netting agreements are not offset on our consolidated balance sheet. Accounting for the gains and losses resulting from changes in the fair value of derivatives depends on the use of the derivative and whether it qualifies for hedge accounting. Derivatives qualify for hedge accounting when they are formally designated as hedges and are effective in reducing the risk exposure that they are designated to hedge. Our assessment of hedge effectiveness is formally documented at hedge inception, and we review hedge effectiveness and measure any ineffectiveness throughout the designated hedge period on at least a quarterly basis. Changes in the fair value of derivatives that are designated as hedges of the variability in expected future cash flows associated with existing recognized assets or liabilities or forecasted transactions ("cash flow hedges") are recorded in accumulated other comprehensive income ("AOCI"). Amounts recorded in AOCI associated with cash flow hedges are subsequently reclassified into contract drilling, depreciation or interest expense as earnings are affected by the underlying hedged forecasted transactions. Gains and losses on a cash flow hedge, or a portion of a cash flow hedge, that no longer qualifies as effective due to an unanticipated change in the forecasted transaction are recognized currently in earnings and included in other, net, in our consolidated statement of operations based on the change in the fair value of the derivative. When a forecasted transaction is probable of not occurring, gains and losses on the derivative previously recorded in AOCI are reclassified currently into earnings and included in other, net, in our consolidated statement of operations. We occasionally enter into derivatives that hedge the fair value of recognized assets or liabilities, but do not designate such derivatives as hedges or the derivatives otherwise do not qualify for hedge accounting. In these situations, a natural hedging relationship generally exists where changes in the fair value of the derivatives offset changes in the fair value of the underlying hedged items. Changes in the fair value of these derivatives are recognized currently in earnings in other, net, in our consolidated statement of operations. Derivatives with asset fair values are reported in other current assets or other assets, net, on our consolidated balance sheet depending on maturity date. Derivatives with liability fair values are reported in accrued liabilities and other, or other liabilities on our consolidated balance sheet depending on maturity date.
Income Taxes | Income Taxes We conduct operations and earn income in numerous countries. Current income taxes are recognized for the amount of taxes payable or refundable based on the laws and income tax rates in the taxing jurisdictions in which operations are conducted and income is earned. Deferred tax assets and liabilities are recognized for the anticipated future tax effects of temporary differences between the financial statement basis and the tax basis of our assets and liabilities using the enacted tax rates in effect at year-end. A valuation allowance for deferred tax assets is recorded when it is more-likely-than-not that the benefit from the deferred tax asset will not be realized. We do not offset deferred tax assets and deferred tax liabilities attributable to different tax paying jurisdictions. We operate in certain jurisdictions where tax laws relating to the offshore drilling industry are not well developed and change frequently. Furthermore, we may enter into transactions with affiliates or employ other tax planning strategies that generally are subject to complex tax regulations. As a result of the foregoing, the tax liabilities and assets we recognize in our financial statements may differ from the tax positions taken, or expected to be taken, in our tax returns. Our tax positions are evaluated for recognition using a more-likely-than-not threshold, and those tax positions requiring recognition are measured as the largest amount of tax benefit that is greater than 50% likely of being realized upon effective settlement with a taxing authority that has full knowledge of all relevant information. Interest and penalties relating to income taxes are included in current income tax expense in our consolidated statement of operations. Our drilling rigs frequently move from one taxing jurisdiction to another based on where they are contracted to perform drilling services. The movement of drilling rigs among taxing jurisdictions may involve a transfer of drilling rig ownership among our subsidiaries (“intercompany rig sale”). The pre-tax profit resulting from an intercompany rig sale is eliminated from our consolidated financial statements, and the carrying value of a rig sold in an intercompany transaction remains at historical net depreciated cost prior to the transaction. Our consolidated financial statements do not reflect the asset disposition transaction of the selling subsidiary or the asset acquisition transaction of the acquiring subsidiary. Income taxes resulting from an intercompany rig sale, as well as the tax effect of any reversing temporary differences resulting from the sale, are deferred and amortized on a straight-line basis over the remaining useful life of the rig. In some instances, we may determine that certain temporary differences will not result in a taxable or deductible amount in future years, as it is more-likely-than-not we will commence operations and depart from a given taxing jurisdiction without such temporary differences being recovered or settled. Under these circumstances, no future tax consequences are expected and no deferred taxes are recognized in connection with such operations. We evaluate these determinations on a periodic basis and, in the event our expectations relative to future tax consequences change, the applicable deferred taxes are recognized or derecognized. We do not provide deferred taxes on the undistributed earnings of certain subsidiaries because our policy and intention is to reinvest such earnings indefinitely. See "Note 9 - Income Taxes" for additional information on our deferred taxes, unrecognized tax benefits, intercompany transfers of drilling rigs and undistributed earnings.
Share-Based Compensation | Share-Based Compensation We sponsor share-based compensation plans that provide equity compensation to our key employees, officers and non-employee directors. Share-based compensation cost is measured at fair value on the date of grant and recognized on a straight-line basis over the requisite service period (usually the vesting period). The amount of compensation cost recognized in our consolidated statement of operations is based on the awards ultimately expected to vest and, therefore, reduced for estimated forfeitures. All changes in estimated forfeitures are based on historical experience and are recognized as a cumulative adjustment to compensation cost in the period in which they occur. See "Note 7 - Benefit Plans" for additional information on our share-based compensation.
Fair Value Measurements | Fair Value Measurements We measure certain of our assets and liabilities based on a fair value hierarchy that prioritizes the inputs to valuation techniques used to measure fair value. The hierarchy assigns the highest priority to unadjusted quoted prices in active markets for identical assets or liabilities ("Level 1") and the lowest priority to unobservable inputs ("Level 3"). Level 2 measurements represent inputs that are observable for similar assets or liabilities, either directly or indirectly, other than quoted prices included within Level 1. See "Note 2 - Fair Value Measurements" for additional information on the fair value measurement of certain of our assets and liabilities.
Earnings Per Share | Earnings Per Share We compute basic and diluted earnings per share ("EPS") in accordance with the two-class method. Net (loss) income attributable to Ensco used in our computations of basic and diluted EPS is adjusted to exclude net income allocated to non-vested shares granted to our employees and non-employee directors. Weighted-average shares outstanding used in our computation of diluted EPS is calculated using the treasury stock method and includes the effect of all potentially dilutive performance awards and excludes non-vested shares. The following table is a reconciliation of (loss) income from continuing operations attributable to Ensco shares used in our basic and diluted EPS computations for each of the years in the three-year period ended December 31, 2015 (in millions):
| 2015 |  | 2014 |  | 2013
(Loss) income from continuing operations attributable to Ensco | $ | (1,466.1 | ) |  | $ | (2,703.1 | ) |  | $ | 1,421.6 |
Income from continuing operations allocated to non-vested share awards | (2.0 | ) |  | (7.9 | ) |  | (15.1 | )
(Loss) income from continuing operations attributable to Ensco shares | $ | (1,468.1 | ) |  | $ | (2,711.0 | ) |  | $ | 1,406.5 |
The following table is a reconciliation of the weighted-average shares used in our basic and diluted earnings per share computations for each of the years in the three-year period ended December 31, 2015 (in millions):
| 2015 |  | 2014 |  | 2013
Weighted-average shares - basic | 232.2 |  |  | 231.6 |  |  | 230.9 |
Potentially dilutive shares | — |  |  | — |  |  | .2 |
Weighted-average shares - diluted | 232.2 |  |  | 231.6 |  |  | 231.1 |
Antidilutive share options totaling 800,000, 400,000 and 300,000 for the years ended December 31, 2015, 2014 and 2013, respectively, were excluded from the computation of diluted EPS.

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- Definition Disclosure of accounting policy for (1) transactions denominated in a currency other than the reporting enterprise's functional currency, (2) translating foreign currency financial statements that are incorporated into the financial statements of the reporting enterprise by consolidation, combination, or the equity method of accounting, and (3) remeasurement of the financial statements of a foreign reporting enterprise in a hyperinflationary economy. + References Reference 1: http://www.xbrl.org/2003/role/presentationRef -Publisher FASB -Name Accounting Standards Codification -Topic 235 -SubTopic 10 -Section 50 -Paragraph 3 -URI http://asc.fasb.org/extlink&oid=51655414&loc=d3e18780-107790 Reference 2: http://www.xbrl.org/2003/role/presentationRef -Publisher FASB -Name Accounting Standards Codification -Topic 830 -SubTopic 30 -Section 50 -Paragraph 1 -URI http://asc.fasb.org/extlink&oid=6450520&loc=d3e32583-110901 Reference 3: http://www.xbrl.org/2003/role/presentationRef -Publisher FASB -Name Accounting Standards Codification -Topic 830 -SubTopic 20 -Section 50 -Paragraph 1 -URI http://asc.fasb.org/extlink&oid=6450222&loc=d3e30840-110895 + Details
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- Definition Disclosure of accounting policy for goodwill and intangible assets. This accounting policy also may address how an entity assesses and measures impairment of goodwill and intangible assets. + References Reference 1: http://www.xbrl.org/2003/role/presentationRef -Publisher FASB -Name Accounting Standards Codification -Topic 350 -SubTopic 30 -Section 50 -Paragraph 1 -URI http://asc.fasb.org/extlink&oid=26713463&loc=d3e16265-109275 Reference 2: http://www.xbrl.org/2003/role/presentationRef -Publisher FASB -Name Accounting Standards Codification -Topic 235 -SubTopic 10 -Section 50 -Paragraph 3 -URI http://asc.fasb.org/extlink&oid=51655414&loc=d3e18780-107790 Reference 3: http://www.xbrl.org/2003/role/presentationRef -Publisher FASB -Name Accounting Standards Codification -Topic 350 -SubTopic 20 -Section 50 -Paragraph 1 -URI http://asc.fasb.org/extlink&oid=35741047&loc=d3e13816-109267 + Details
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- Definition Disclosure of accounting policy for income taxes, which may include its accounting policies for recognizing and measuring deferred tax assets and liabilities and related valuation allowances, recognizing investment tax credits, operating loss carryforwards, tax credit carryforwards, and other carryforwards, methodologies for determining its effective income tax rate and the characterization of interest and penalties in the financial statements. + References Reference 1: http://www.xbrl.org/2003/role/presentationRef -Publisher FASB -Name Accounting Standards Codification -Topic 235 -SubTopic 10 -Section 50 -Paragraph 3 -URI http://asc.fasb.org/extlink&oid=51655414&loc=d3e18780-107790 Reference 2: http://www.xbrl.org/2003/role/presentationRef -Publisher FASB -Name Accounting Standards Codification -Topic 740 -SubTopic 10 -Section 50 -Paragraph 19 -URI http://asc.fasb.org/extlink&oid=6907707&loc=d3e32840-109319 Reference 3: http://www.xbrl.org/2003/role/presentationRef -Publisher FASB -Name Accounting Standards Codification -Topic 740 -SubTopic 30 -Section 05 -Paragraph 1 -URI http://asc.fasb.org/extlink&oid=6423966&loc=d3e40913-109327 Reference 4: http://www.xbrl.org/2003/role/presentationRef -Publisher FASB -Name Accounting Standards Codification -Topic 954 -SubTopic 740 -Section 50 -Paragraph 1 -URI http://asc.fasb.org/extlink&oid=6491622&loc=d3e9504-115650 Reference 5: http://www.xbrl.org/2003/role/presentationRef -Publisher FASB -Name Accounting Standards Codification -Topic 740 -SubTopic 10 -Section 50 -Paragraph 17 -Subparagraph (b) -URI http://asc.fasb.org/extlink&oid=6907707&loc=d3e32809-109319 Reference 6: http://www.xbrl.org/2003/role/presentationRef -Publisher FASB -Name Accounting Standards Codification -Topic 740 -SubTopic 10 -Section 45 -Paragraph 25 -URI http://asc.fasb.org/extlink&oid=37586315&loc=d3e32247-109318 Reference 7: http://www.xbrl.org/2003/role/presentationRef -Publisher FASB -Name Accounting Standards Codification -Topic 740 -SubTopic 10 -Section 45 -Paragraph 28 -URI http://asc.fasb.org/extlink&oid=37586315&loc=d3e32280-109318 + Details
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- Definition The entire disclosure for the nature of an entity's business, major products or services, principal markets including location, and the relative importance of its operations in each business and the basis for the determination, including but not limited to, assets, revenues, or earnings. For an entity that has not commenced principal operations, disclosures about the risks and uncertainties related to the activities in which the entity is currently engaged and an understanding of what those activities are being directed toward. + References Reference 1: http://www.xbrl.org/2003/role/presentationRef -Publisher FASB -Name Accounting Standards Codification -Topic 275 -SubTopic 10 -Section 50 -Paragraph 2 -URI http://asc.fasb.org/extlink&oid=51801978&loc=d3e6003-108592 Reference 2: http://www.xbrl.org/2003/role/presentationRef -Publisher FASB -Name Accounting Standards Codification -Topic 275 -SubTopic 10 -Section 50 -Paragraph 2A -URI http://asc.fasb.org/extlink&oid=51801978&loc=SL51803626-108592 + Details
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- Definition Disclosure of accounting policy for long-lived, physical assets used in the normal conduct of business and not intended for resale. Includes, but is not limited to, basis of assets, depreciation and depletion methods used, including composite deprecation, estimated useful lives, capitalization policy, accounting treatment for costs incurred for repairs and maintenance, capitalized interest and the method it is calculated, disposals and impairments. + References Reference 1: http://www.xbrl.org/2003/role/presentationRef -Publisher FASB -Name Accounting Standards Codification -Topic 360 -SubTopic 10 -Section 50 -Paragraph 1 -URI http://asc.fasb.org/extlink&oid=6391035&loc=d3e2868-110229 Reference 2: http://www.xbrl.org/2003/role/presentationRef -Publisher FASB -Name Accounting Standards Codification -Topic 235 -SubTopic 10 -Section 50 -Paragraph 3 -URI http://asc.fasb.org/extlink&oid=51655414&loc=d3e18780-107790 Reference 3: http://www.xbrl.org/2003/role/presentationRef -Publisher FASB -Name Accounting Standards Codification -Topic 210 -SubTopic 10 -Section S99 -Paragraph 1 -Subparagraph (SX 210.5-02.13(a)) -URI http://asc.fasb.org/extlink&oid=6877327&loc=d3e13212-122682 + Details
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