SIGNIFICANT ACCOUNTING POLICIES
|9 Months Ended|
Jun. 30, 2018
|Accounting Policies [Abstract]|
|SIGNIFICANT ACCOUNTING POLICIES||
NOTE 2 – SIGNIFICANT ACCOUNTING POLICIES
The condensed financial statements included herein are unaudited. However, these condensed financial statements include all adjustments (consisting of normal recurring adjustments), which, in the opinion of management are necessary for a fair presentation of financial position, results of operations and cash flows for the interim periods. The results of operations for interim periods are not necessarily indicative of the results to be expected for an entire year. The preparation of financial statements in accordance with U.S. generally accepted accounting principles requires management to make estimates and assumptions that affect the amounts reported in the Company’s condensed financial statements and accompanying notes. Actual results could differ materially from those estimates.
Certain information, accounting policies, and footnote disclosures normally included in the financial statements prepared in accordance with accounting principles generally accepted in the United States of America (“GAAP”) have been omitted in this Form 10-Q pursuant to certain rules and regulations of the Securities and Exchange Commission (“SEC”). The condensed financial statements should be read in conjunction with the audited financial statements for the year ended September 30, 2017, which were included in the Company’s Annual Report on Form 10-K for the fiscal year ended September 30, 2017 and filed with the Securities and Exchange Commission on December 29, 2017.
GulfSlope considers highly liquid investments with insignificant interest rate risk and original maturities to the Company of three months or less to be cash equivalents. Cash equivalents consist primarily of interest-bearing bank accounts and money market funds.
The Company has incurred accumulated losses as of June 30, 2018 of $41.3 million. Further losses are anticipated in developing our business. As a result, there exists substantial doubt about our ability to continue as a going concern. As of June 30, 2018, we had $4.9 million of unrestricted cash on hand, $3.2 million of this amount is for the payment of joint payables for drilling operations. The Company estimates that it will need to raise a minimum of $7.5 million to meet its obligations and planned expenditures through August 2019. The Company plans to finance its operations through the issuance of equity and debt offerings. Our policy has been to periodically raise funds through the sale of equity on a limited basis, to avoid undue dilution while at the early stages of execution of our business plan. Short term needs have been historically funded through loans from executive management and other related parties. There are no assurances that financing will be available with acceptable terms, if at all. If the Company is not successful in obtaining adequate financing, operations would need to be curtailed or ceased, including those associated with being a public reporting company. The financial statements do not include any adjustments that might result from the outcome of this uncertainty.
Full Cost Method
The Company uses the full cost method of accounting for its oil and gas exploration and development activities as defined by the Securities and Exchange Commission (“SEC”). Under the full cost method of accounting, all costs associated with successful and unsuccessful exploration and development activities are capitalized on a country-by-country basis into a single cost center (“full cost pool”). Such costs include property acquisition costs, geological and geophysical (“G&G”) costs, carrying charges on non-producing properties, costs of drilling both productive and non-productive wells and overhead charges directly related to acquisition, exploration and development activities. Proceeds from property sales will generally be credited to the full cost pool, with no gain or loss recognized, unless such a sale would significantly alter the relationship between capitalized costs and the proved reserves attributable to these costs. A significant alteration would typically involve a sale of 25% or more of the proved reserves related to a single full cost pool. Proved properties are amortized on a country-by-country basis using the units of production method (UOP). The UOP calculation multiplies the percentage of estimated proved reserves produced each quarter by the cost of those reserves. The amortization base in the UOP calculation includes the sum of proved property, net of accumulated depreciation, depletion and amortization (DD&A), estimated future development costs (future costs to access and develop proved reserves), and asset retirement costs, less related salvage value.
The costs of unproved properties and related capitalized costs (such as G&G costs) are withheld from the amortization calculation until such time as they are either developed or abandoned. Unproved properties and properties under development are reviewed for impairment at least quarterly and are determined through an evaluation considering, among other factors, seismic data, requirements to relinquish acreage, drilling results, remaining time in the commitment period, remaining capital plan, and political, economic, and market conditions. In countries where proved reserves exist, exploratory drilling costs associated with dry holes are transferred to proved properties immediately upon determination that a well is dry and amortized accordingly. In countries where a reserve base has not yet been established, impairments are charged to earnings.
Companies that use the full cost method of accounting for oil and natural gas exploration and development activities are required to perform a ceiling test calculation each quarter. The full cost ceiling test is an impairment test prescribed by SEC Regulation S-X Rule 4-10. The ceiling test is performed quarterly, on a country-by-country basis, utilizing the average of prices in effect on the first day of the month for the preceding twelve-month period. The ceiling limits such pooled costs to the aggregate of the present value of future net revenues attributable to proved crude oil and natural gas reserves discounted at 10%, plus the lower of cost or market value of unproved properties less any associated tax effects. If such capitalized costs exceed the ceiling, the Company will record a write-down to the extent of such excess as a non-cash charge to earnings. Any such write-down will reduce earnings in the period of occurrence and results in a lower depreciation, depletion and amortization rate in future periods. A write-down may not be reversed in future periods even though higher oil and natural gas prices may subsequently increase the ceiling.
As of June 30, 2018, the Company’s oil and gas properties consisted of wells in process, capitalized exploration and acquisition costs for unproved properties and no proved reserves.
Basic and Dilutive Earnings Per Share
Basic (loss) per share (“EPS”) is computed by dividing net income (loss) (the numerator) by the weighted average number of common shares outstanding for the period (denominator). Diluted EPS is computed by dividing net income (loss) by the weighted average number of common shares and potential common shares outstanding (if dilutive) during each period. Potential common shares include stock options, warrants, and restricted stock. The number of potential common shares outstanding relating to stock options, warrants, and restricted stock is computed using the treasury stock method.
As the Company has incurred losses for the nine months ended June 30, 2018 and 2017, the potentially dilutive shares are anti-dilutive and are thus not added into the loss per share calculations. As of June 30, 2018 and 2017, there were 214,418,438 and 163,805,888 potentially dilutive shares, respectively.
Recent Accounting Pronouncements
In May 2014, the FASB issued ASU 2014-09, Revenue from Contracts with Customers (Topic 606). ASU 2014-09 is amended by ASU 2015-14, ASU 2016-08, ASU 2016-10, ASU 2016-11, ASU 2016-12, ASU 2016-20, ASU 2017-10, ASU 2017-13 and ASU 2017-14, which FASB issued in August 2015, March 2016, April 2016, May 2016, May 2016, December 2016, May 2017, September 2017 and November 2017, respectively (collectively, the amended ASU 2014-09). The amended ASU 2014-09 provides a single comprehensive model for the recognition of revenue arising from contracts with customers and supersedes most current revenue recognition guidance, including industry-specific guidance. It requires an entity to recognize revenue when the entity transfers promised goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods or services. The amended ASU 2014-09 creates a five-step model that requires entities to exercise judgment when considering the terms of contract(s), which includes (1) identifying the contract(s) with the customer, (2) identifying the separate performance obligations in the contract, (3) determining the transaction price, (4) allocating the transaction price to the separate performance obligations, and (5) recognizing revenue as each performance obligation is satisfied. The amended ASU 2014-09 requires additional disclosure about the nature, amount, timing and uncertainty of revenue and cash flows arising from customer contracts, including qualitative and quantitative information about contracts with customers, significant judgments and changes in judgments and assets recognized from costs incurred to obtain or fulfill a contract. The effective date for the amended ASU 2014-09 for the Company is fiscal year 2019, including interim reporting periods within that reporting period. Early adoption is permitted for fiscal year 2018, including interim reporting periods within that reporting period. ASU 2014-09 will be effective for us in our first quarter of fiscal 2019. We have evaluated the impact of adoption of this standard and determined that it will not have a material impact on our financial statements.
On February 25, 2016, the FASB issued ASU No. 2016-02, Leases (Topic 842). The new guidance establishes the principles to report transparent and economically neutral information about the assets and liabilities that arise from leases. The new guidance is effective for fiscal years beginning after December 15, 2018, including interim periods within those fiscal years, and early application is permitted for all organizations. The Company has not yet selected the period during which it will implement this pronouncement, and it is currently evaluating the impact the adoption of ASU 2016-02 will have on its financial statements. In terms of the Company’s evaluation efforts, the Company has assigned internal resources and engaged third party service providers to assist in its evaluation. We expect this evaluation to be completed by the end of our fiscal year, September 30, 2018.
The Company has evaluated all other recent accounting pronouncements and believes that none of them will have a significant effect on the Company’s financial statements.
Recent Tax and Financial Legislation
The Tax Cuts and Jobs Act of 2017 was signed into law on December 22, 2017 by President Donald J. Trump. The law includes significant changes to the U.S. corporate income tax system, including a Federal corporate rate reduction from 35% to 21%, limitations on the deductibility of interest expense and executive compensation, and the transition of U.S. international taxation from a worldwide tax system to a territorial tax system. We are in the process of analyzing the final legislation and determining an estimate of the financial impact.
The entire disclosure for all significant accounting policies of the reporting entity.
Reference 1: http://www.xbrl.org/2003/role/presentationRef