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Summary of Significant Accounting Policies (Policies) | 12 Months Ended
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Dec. 31, 2017
Accounting Policies [Abstract] |
Organization and Nature of Operations | Organization and Nature of Operations Approach Resources Inc. (“Approach,” the “Company,” “we,” “us” or “our”) is an independent energy company focused on the exploration, development, production and acquisition of unconventional oil and gas properties. We focus on finding and developing oil and natural gas reserves in oil shale and tight gas sands. Our properties are primarily located in the Permian Basin in West Texas. We also own interests in the East Texas Basin.
Consolidation, Basis of Presentation and Significant Estimates | Consolidation, Basis of Presentation and Significant Estimates The accompanying consolidated financial statements have been prepared in accordance with accounting principles generally accepted in the United States of America and include the accounts of the Company and its wholly owned subsidiaries. Intercompany accounts and transactions are eliminated. In preparing the accompanying financial statements, management has made certain estimates and assumptions that affect reported amounts in the financial statements and disclosures of contingencies. Actual results may differ from those estimates. Significant assumptions are required in the valuation of proved oil and natural gas reserves, which affect our estimate of depletion expense as well as our impairment analyses. Significant assumptions also are required in our estimation of accrued liabilities, commodity derivatives, income tax provision, share-based compensation and asset retirement obligations. It is at least reasonably possible these estimates could be revised in the near term, and these revisions could be material. Certain prior-year amounts have been reclassified to conform to current-year presentation. These classifications have no impact on the net loss reported.
Cash and Cash Equivalents | Cash and Cash Equivalents We consider all highly liquid debt instruments purchased with an original maturity of three months or less to be cash equivalents. At times, the amount of cash and cash equivalents on deposit in financial institutions exceeds federally insured limits. We monitor the soundness of the financial institutions and believe the Company’s risk is negligible.
Capitalized Costs | Capitalized Costs. Our oil and gas properties comprised the following (in thousands):
|  | December 31, |
|  | 2017 |  |  | 2016 |
Mineral interests in properties: |  |  |  |  |  |  |  |
Unproved leasehold costs |  | $ | 28,737 |  |  | $ | 33,596 |
Proved leasehold costs |  |  | 60,077 |  |  |  | 44,643 |
Wells and related equipment and facilities |  |  | 1,819,836 |  |  |  | 1,774,314 |
Support equipment |  |  | 8,459 |  |  |  | 8,002 |
Uncompleted wells, equipment and facilities |  |  | 13,468 |  |  |  | 9,219 |
Total costs |  |  | 1,930,577 |  |  |  | 1,869,774 |
Less accumulated depreciation, depletion and amortization |  |  | (850,301 | ) |  |  | (780,412 | )
Net capitalized costs |  | $ | 1,080,276 |  |  | $ | 1,089,362 |
We follow the successful efforts method of accounting for our oil and gas producing activities. Costs to acquire mineral interests in oil and gas properties and to drill and equip development wells and related asset retirement costs are capitalized. Costs to drill exploratory wells are capitalized pending determination of whether the wells have proved reserves. If we determine that the wells do not have proved reserves, the costs are charged to exploration expense. There were no exploratory wells capitalized, pending determination of whether the wells have proved reserves, at December 31, 2017 or 2016. Geological and geophysical costs, including seismic studies are charged to exploration expense as incurred. We capitalize interest on expenditures for significant exploration and development projects that last more than six months while activities are in progress to bring the assets to their intended use and while these expenditures are excluded from our depletable base. Through December 31, 2017, we have capitalized no interest costs because our individual wells and infrastructure projects are generally developed in less than six months. Costs incurred to maintain wells and related equipment are charged to expense as incurred. On the sale or retirement of a complete unit of a proved property, the cost and related accumulated depreciation, depletion and amortization are eliminated from the property accounts, and the resulting gain or loss is recognized. On the retirement or sale of a partial unit of proved property, the cost is charged to accumulated depreciation, depletion and amortization with no gain or loss recognized in income. Capitalized amounts attributable to proved oil and gas properties are depleted by the unit-of-production method over proved reserves using the unit conversion ratio of six Mcf of gas to one barrel of oil equivalent (“Boe”), and one barrel of NGLs to one Boe. The ratios of six Mcf of natural gas to one Boe and one barrel of NGLs to one Boe do not assume price equivalency and, given price differentials, the price for a Boe for natural gas may differ significantly from the price for a barrel of oil. Depreciation, depletion and amortization expense for oil and gas producing property and related equipment was $70.3 million, $78.7 million and $108.8 million for the years ended December 31, 2017, 2016 and 2015, respectively. Capitalized costs related to proved oil and gas properties, including wells and related equipment and facilities, are periodically evaluated for impairment based on an analysis of undiscounted future net cash flows in accordance with ASC 360, Accounting for the Impairment or Disposal of Long-Lived Assets, as events or changes in circumstances indicate that the carrying values of those assets may not be recoverable. If undiscounted cash flows are insufficient to recover the net capitalized costs related to proved properties, then we recognize an impairment charge equal to the difference between the net capitalized costs related to proved properties and their estimated fair values based on the present value of the related future net cash flows. Estimating future net cash flows involves the use of judgments, including estimation of the proved and unproved oil and natural gas reserve quantities, timing of development and production, expected future commodity prices, capital expenditures and production costs. We recorded no impairment of our proved properties for the years ended December 31, 2017 and 2016. During the year ended December 31, 2015, we recognized an impairment loss of $214.7 million related primarily to our vertical Canyon wells. See Note 7 for proved property impairment disclosures. Unproved oil and gas properties that are individually significant are periodically assessed for impairment of value, and a loss is recognized at the time of impairment by providing an impairment allowance. We recorded no impairment of our unproved properties for the years ended December 31, 2017 and 2016. Certain leases that we consider non-core to our development of Project Pangea were impaired during the year ended December 31, 2015, as we did not plan to develop them. As a result, we recorded a non-cash impairment loss of unproved property of $5.5 million for the year ended December 31, 2015. The total impairment loss of $220.2 million for the year ended December 31, 2015, is recorded in impairment of oil and gas properties on our consolidated statements of operations, and in accumulated depletion, depreciation and amortization on our consolidated balance sheets. On the sale of an entire interest in an unproved property for cash or cash equivalents, gain or loss on the sale is recognized, taking into consideration the amount of any recorded impairment if the property had been assessed individually. If a partial interest in an unproved property is sold, the amount received is treated as a reduction of the cost of the interest retained. F-1
Other Property | Other Property Furniture, fixtures and equipment are carried at cost. Depreciation of furniture, fixtures and equipment is provided using the straight-line method over estimated useful lives ranging from three to 15 years. Gain or loss on retirement or sale or other disposition of assets is included in income in the period of disposition. Depreciation expense for other property and equipment was $237,000, $343,000 and $563,000 for the years ended December 31, 2017, 2016 and 2015, respectively.
Financial Instruments | Financial Instruments The carrying amounts of financial instruments including cash and cash equivalents, accounts receivable, accounts payable and accrued liabilities approximate fair value, as of December 31, 2017 and 2016. See Note 7 for fair value disclosures.
Income Taxes | Income Taxes We are subject to U.S. federal income taxes along with state income taxes in Texas. When tax returns are filed, it is highly certain that some positions taken would be sustained upon examination by the taxing authorities, while others are subject to uncertainty about the merits of the position taken or the amount of the position that would be ultimately sustained. The benefit of a tax position is recognized in the financial statements in the period during which, based on all available evidence, management believes it is more likely than not that the position will be sustained upon examination, including the resolution of appeals or litigation processes, if any. Tax positions taken are not offset or aggregated with other positions. Tax positions that meet the more-likely-than-not recognition threshold are measured as the largest amount of tax benefit that is more than 50% likely of being realized upon settlement with the applicable taxing authority. The portion of the benefits associated with tax positions taken that exceeds the amount measured as described above is reflected as a liability for unrecognized tax benefits in the accompanying balance sheet along with any associated interest and penalties that would be payable to the taxing authorities upon examination. Interest and penalties associated with unrecognized tax benefits are classified as additional income taxes on the consolidated statements of operations. Based on our analysis, we did not have any uncertain tax positions as of December 31, 2017 or 2016. The Company’s income tax returns are subject to examination by the relevant taxing authorities as follows: U.S. Federal income tax returns for tax years 2014 and forward and Texas income and margin tax returns for tax years 2014 and forward. There are currently no income tax examinations underway for these jurisdictions. Deferred tax assets and liabilities are recognized for the estimated future tax consequences attributable to the 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 the tax rate in effect for the year in which those temporary differences are expected to be recovered or settled. The effect of a change in tax rates on deferred tax assets and liabilities is recognized in income in the year of the enacted tax rate change. We monitor our deferred tax assets by jurisdiction to assess their potential realization, and a valuation allowance is recognized on deferred tax assets when we believe that certain of these assets are more likely than not to be realized. In performing this review, we make estimates and assumptions regarding projected future taxable income, the expected timing of reversals of existing temporary differences and the implementation of tax planning strategies. To the extent that a valuation allowance is established or changed during any period, we would recognize expense or benefit within our consolidated tax expense. We currently have a valuation allowance of $0.5 million on our deferred tax assets, after accounting for the change in the corporate federal income tax rate under the Tax Cuts and Jobs Act.
Derivative Activity | Derivative Activity We record our open derivative instruments at fair value on our consolidated balance sheets as either derivative assets or liabilities. Cash settlements and changes in the fair value of our commodity derivative contracts are recorded in earnings as they occur on our consolidated statements of operations under the caption entitled “commodity derivative (loss) gain.” We have not historically designated our derivative instruments as cash-flow hedges; however we use those instruments to reduce our exposure to fluctuations in commodity prices related to our natural gas and oil production. Derivative assets and derivative liabilities, at fair value, are included on our consolidated balance sheets as current or non-current assets or liabilities based on the anticipated timing of cash settlements under the related contracts.
Prepaid Expenses and Other Assets | Prepaid Expenses and Other Assets In April 2017, we entered into an agreement that secured pricing and availability of a dedicated hydraulic fracturing services crew. Under this agreement, we made a prepayment of $5 million, to be used as we completed wells. We have used $0.7 million of this prepayment related to hydraulic fracturing services provided during the first year of the agreement. As of December 31, 2017, we maintained an unused prepaid balance of $4.3 million in prepaid expenses and other current assets on our consolidated balance sheets related to this agreement. After December 31, 2017, we used an additional $0.5 million of this prepayment and $3.8 million of the unused prepaid balance was refunded to us.
Accrued Liabilities | Accrued Liabilities The following is a summary of our accrued liabilities at December 31, 2017 and 2016 (in thousands):
|  | 2017 |  |  | 2016 |
Capital expenditures accrual |  | $ | 1,522 |  |  | $ | 1,067 |
Operating expenses and other |  |  | 6,551 |  |  |  | 6,750 |
Total |  | $ | 8,073 |  |  | $ | 7,817 |
Asset Retirement Obligations | Asset Retirement Obligations Our asset retirement obligations relate to future plugging and abandonment expenses on oil and gas properties. Based on the expected timing of payments, the full asset retirement obligation is classified as non-current. There were no significant changes to the asset retirement obligations for the years ended December 31, 2017, 2016 and 2015.
Share-Based Compensation | Share-Based Compensation We measure and record compensation expense for share-based payment awards to employees and outside directors based on estimated grant date fair values. We recognize compensation costs for awards granted over the requisite service period based on the grant date fair value in general and administrative expenses on our consolidated statements of operations. Additionally, we recognize forfeitures of share-based compensation as they occur. In 2016, we awarded cash-settled performance awards, subject to certain performance conditions, to our executive officers. The cash-settled performance awards represent a non-equity unit with a conversion value equal to the fair market value of a share of the Company’s common stock at the vesting date. These awards are classified as liability awards due to the cash settlement feature. Compensation costs associated with the cash-settled performance awards are re-measured at each interim reporting period and an adjustment is recorded in general and administrative expenses on our consolidated statements of operations.
Earnings Per Common Share | Earnings Per Common Share We report basic earnings per common share, which excludes the effect of potentially dilutive securities, and diluted earnings per common share, which includes the effect of all potentially dilutive securities unless their impact is antidilutive. The following are reconciliations of the numerators and denominators of our basic and diluted earnings per share, (dollars in thousands, except per-share amounts):
|  | For the Years Ended December 31, |
|  | 2017 |  |  | 2016 |  |  | 2015 |
Income (numerator): |  |  |  |  |  |  |  |  |  |  |  |
Net (loss) income — basic |  | $ | (112,359 | ) |  | $ | (52,243 | ) |  | $ | (174,104 | )
Weighted average shares (denominator): |  |  |  |  |  |  |  |  |  |  |  |
Weighted average shares — basic |  |  | 83,404,104 |  |  |  | 41,488,206 |  |  |  | 40,464,283 |
Dilution effect of share-based compensation, treasury method (1) |  |  | — |  |  |  | — |  |  |  | — |
Weighted average shares — diluted |  |  | 83,404,104 |  |  |  | 41,488,206 |  |  |  | 40,464,283 |
Net (loss) income per share: |  |  |  |  |  |  |  |  |  |  |  |
Basic |  | $ | (1.35 | ) |  | $ | (1.26 | ) |  | $ | (4.30 | )
Diluted |  | $ | (1.35 | ) |  | $ | (1.26 | ) |  | $ | (4.30 | )
(1) | Approximately 39,000 options to purchase our common stock were excluded from this calculation because they were antidilutive for the years ended December 31, 2016 and 2015. No options were outstanding as of December 31, 2017, as they had expired.
Revenue and Accounts Receivable from Purchasers and Joint Interest Owners | Revenue and Accounts Receivable. We recognize revenue for our production when the quantities are delivered to or collected by the respective purchaser. Prices for such production are defined in sales contracts and are readily determinable based on certain publicly available indices. Accounts receivable, joint interest owners, consist of uncollateralized joint interest owner obligations due within 30 days of the invoice date. Accounts receivable, oil, NGLs and gas sales, consist of uncollateralized accrued revenues due under normal trade terms, generally requiring payment within 30 to 60 days of production. No interest is charged on past-due balances. Payments made on all accounts receivable are applied to the earliest unpaid items. We review accounts receivable periodically and reduce the carrying amount by a valuation allowance that reflects our best estimate of the amount that may not be collectible. No such allowance was considered necessary at December 31, 2017 or 2016.
Oil and Gas Sales Payable | Oil, NGLs and Gas Sales Payable. Oil, NGLs and gas sales payable represents amounts collected from purchasers for oil, NGLs and gas sales which are either revenues due to other revenue interest owners or severance taxes due to the respective state or local tax authorities. Generally, we are required to remit amounts due under these liabilities within 60 days of the end of the month in which the related production occurred.
Production Costs | Production Costs. Production costs, including compressor rental and repair, pumpers’ and supervisors’ salaries, saltwater disposal, insurance, repairs and maintenance, expensed workovers and other operating expenses are expensed as incurred and included in lease operating expense s on our consolidated statements of operations.
Exploration expenses | Exploration expenses. Exploration expenses include lease expirations, delay rentals, geological and geophysical costs and dry hole costs. For the year ended December 31, 2015 exploration expense includes $2.2 million related to the early termination of daywork drilling contracts.
Dependence on Major Customer | Dependence on Major Customers. For the year ended December 31, 201 7, sales to American Midstream, LP (“AMID”), a successor to JP Energy Development, LP (“JP Energy”), and DCP Midstream, LP (“DCP”) accounted for approximately 52% and 47%, respectively, of our total sales. As of December 31, 2017, we had dedicated the majority of our oil production from Project Pangea through September 2022 to AMID. In addition, as of December 31, 2017, we had contracted to sell the majority of our NGLs and natural gas production from Project Pangea to DCP through August 2023. For the year ended December 31, 2016, sales to DCP and JP Energy accounted for approximately 46% and 54%, respectively of our total sales. For the year ended December 31, 2015, sales to DCP and JP Energy accounted for approximately 36% and 63%, respectively of our total sales. We believe that there are potential alternative purchasers and that it may be necessary to establish relationships with new purchasers. However, there can be no assurance that we can establish such relationships and that those relationships will result in increased purchasers. Although we are exposed to a concentration of credit risk, we believe that all of our purchasers are credit worthy.
Segment Reporting | Segment Reporting The Company presently operates in one business segment, the exploration and production of oil, NGLs and natural gas.
Recent Accounting Pronouncements | Recent Accounting Pronouncements In May 2014, the Financial Accounting Standards Board (the “FASB”) issued an accounting standards update for “Revenue from Contracts with Customers,” which supersedes the revenue recognition requirements in “Topic 605, Revenue Recognition.” This accounting standard update provides new guidance concerning recognition and measurement of revenue and requires additional disclosures about the nature, timing and uncertainty of revenue and cash flows arising from contracts with customers. This new guidance permits adoption through the use of either a full retrospective approach or a modified retrospective approach for annual reporting periods beginning on or after December 15, 2016, with early adoption not permitted. In August 2015, FASB delayed the effective date one year, making the new standard effective for interim periods and annual periods beginning after December 15, 2017. We have completed our detailed review of our individual purchaser contracts and we have evaluated the impact of this accounting standards update on our consolidated financial statements. We adopted this standard using the modified retrospective method of adoption on January 1, 2018. Adoption of this standard did not have a significant impact on our consolidated statements of operations or cash flows. We implemented processes to ensure new contracts are reviewed for the appropriate accounting treatment and generate the disclosures required under the new standard. Additional disclosures will be required to describe the nature, amount, timing and uncertainty of revenue and cash flows from contracts with customers including disaggregation of revenue and remaining performance obligations, beginning with our Form 10-Q for the three months ended March 31, 2018. In February 2016, FASB issued an accounting standards update for “Leases,” which amends existing guidance to require lessees to recognize assets and liabilities on the balance sheet for the rights and obligations created by long-term leases and to disclose additional quantitative and qualitative information about leasing arrangements. This new guidance is effective for interim and annual periods beginning after December 15, 2018, and we will adopt it using a modified retrospective approach. Currently, the Company is evaluating the standard’s applicability to our various contractual arrangements. We believe that the adoption this standard will result in recognition of assets and liabilities on the balance sheet for current operating leases. The Company is still evaluating the impact of this new guidance on its consolidated financial statements. In March 2016, FASB issued an accounting standards update for “Compensation — Stock Compensation,” which amends existing guidance related to the accounting for forfeitures, employer tax withholding on share-based compensation and financial statement presentation of excess tax benefits or deficiencies. This standard is effective for interim and annual reporting periods beginning after December 15, 2016, with early adoption permitted. We applied this standard using a modified retrospective approach. We have elected to (i) recognize forfeitures of share-based compensation as they occur, (ii) permit tax withholdings in excess of the minimum statutory requirements and (iii) recognize previously un-recognized excess tax benefits related to share-based compensation in the current year. As a result, we have recognized an increase in accumulated earnings in the current year of $1.7 million related to the change in accounting principal as of January 1, 2016. Adoption of this guidance did not impact our consolidated statements of operations or cash flows. In January 2017, FASB issued an accounting standards update for “Clarifying the Definition of a Business,” which provides guidance to assist entities with evaluating whether transactions should be accounted for as acquisitions (or disposals) of assets or businesses. This standard requires entities to use a screen test to determine when an integrated set of assets and activities is not a business or if the integrated set of assets and activities needs to be further evaluated against the framework. This standard is effective for interim and annual reporting periods beginning after December 15, 2016. The Company is evaluating the impact of this new guidance on its consolidated financial statements. In August 2017, FASB issued an accounting standards update for “Derivatives and Hedging,” which amends existing guidance related to the recognition and presentation requirements of hedge accounting, including eliminating the requirement to separately measure and report hedge ineffectiveness, and presenting all items that affect earnings in the same income statement line item as the hedged item. This standard is effective for interim and annual reporting periods beginning after December 15, 2018, with early adoption permitted. We have elected to early adopt this standard in the first quarter of 2018. Adoption of this standard did not impact our consolidated statements of operations or cash flows. Although we have not historically designated our derivative contracts as cash-flow hedges, we may in the future designate commodity derivative contracts as cash-flow hedges.

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- Definition Carrying value as of the balance sheet date of obligations incurred and payable, pertaining to costs that are statutory in nature, are incurred on contractual obligations, or accumulate over time and for which invoices have not yet been received or will not be rendered. Examples include taxes, interest, rent and utilities. + References No definition available. + Details
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- Definition Exploration expenses (including prospecting) related to oil and gas producing entities and would be included in operating expenses of that entity. Costs incurred in identifying areas that may warrant examination and in examining specific areas that are considered to have prospects of containing oil and gas reserves, including costs of drilling exploratory wells and exploratory-type stratigraphic test wells. Exploration costs may be incurred both before acquiring the related property (sometimes referred to in part as prospecting costs) and after acquiring the property. Principal types of exploration costs, which include depreciation and applicable operating costs of support equipment and facilities and other costs of exploration activities, are: (I) Costs of topographical, geographical and geophysical studies, rights of access to properties to conduct those studies, and salaries and other expenses of geologists, geophysical crews, and others conducting those studies. Collectively, these are sometimes referred to as geological and geophysical or "G and G" costs. (ii) Costs of carrying and retaining undeveloped properties, such as delay rentals, ad valorem taxes on properties, legal costs for title defense, and the maintenance of land and lease records. (iii) Dry hole contributions and bottom hole contributions. (iv) Costs of drilling and equipping exploratory wells. (v) Costs of drilling exploratory-type stratigraphic test wells. + References No definition available. + Details
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- Definition Lease expense related to property used in oil and gas production. Costs incurred related to wells drilled or completed for the purpose of supporting production. Costs incurred related to the gas activities, such as transportation, marketing and processing crude oil, natural gas and refined petroleum products. + References No definition available. + Details
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- Definition Amounts collected from purchasers for oil, NGL and gas sales which are either revenues due to other revenue interest owners or severance taxes due to the respective state or local tax authorities. + References No definition available. + Details
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