Summary of Significant Accounting Policies

12 Months Ended

Dec. 31, 2014

Summary of Significant Accounting Policies [Abstract]

Summary of Significant Accounting Policies:

Note 2 Summary of Significant Accounting Policies:

Principles of Consolidation and Presentation

The accompanying consolidated financial statements and related notes have been prepared in accordance with accounting principles generally accepted in the United States of America (“US GAAP”) and include the accounts of the Company and its wholly-owned subsidiaries. All material intercompany balances and transactions have been eliminated in consolidation.

Reclassification

Certain amounts in the prior period financial statements have been reclassified to conform to the current period presentation. These reclassifications had no effect on reported losses.

Use of Estimates

The preparation of consolidated financial statements in conformity with U.S. GAAP requires management to make estimates and assumptions that affect the amounts reported in the consolidated financial statements and accompanying notes. Such estimates and assumptions impact, among others, the following: allowance for bad debt, the fair value of share-based payments, fair value of derivative liabilities, estimates of the probability and potential magnitude of contingent liabilities and the valuation allowance for deferred tax assets due to continuing operating losses.

Making estimates requires management to exercise significant judgment. It is at least reasonably possible that the estimate of the effect of a condition, situation or set of circumstances that existed at the date of the consolidated financial statements, which management considered in formulating its estimate could change in the near term due to one or more future confirming events. Accordingly, the actual results could differ significantly from our estimates.

The accompanying consolidated financial statements contain estimates of the Company’s proved reserves and the estimated future net revenues from the proved reserves. These estimates are based on various assumptions, including assumptions required by the United States Securities and Exchange Commission (“SEC”) relating to oil and gas prices, drilling and operating expenses, capital expenditures, taxes and availability of funds.

The process of estimating oil and gas reserves is complex and involves significant decisions and assumptions in the evaluation of available geological, geophysical, engineering and economic data for each reservoir. Actual future production, oil and gas prices, revenues, taxes, development expenditures, operating expenses and quantities of recoverable oil and gas reserves most likely will vary from these estimates. Such variations may be significant and could materially affect the estimated quantities and present value of our proved reserves. In addition, the Company’s management may adjust estimates of proved reserves to reflect production history, results of exploration and development drilling, prevailing oil and gas prices and other factors, many of which are beyond the Company’s control. The Company’s properties may also be susceptible to hydrocarbon drainage from production by operators on adjacent properties.

The present value of future net cash flows from the Company’s proved reserves is not necessarily the same as the current market value of the Company’s estimated oil and natural gas reserves. The estimated discounted future net cash flows from the Company’s proved reserves is based on the average, first-day-of-the-month price during the 12-month period preceding the measurement date. Actual future net cash flows from oil and natural gas properties also will be affected by factors such as actual prices received for oil and gas, actual development and production costs, the amount and timing of actual production, the supply of and demand for oil and gas, and changes in governmental regulations or taxes.

The timing of the Company’s production and incurrence of expenses in connection with the development and production of oil and natural gas properties will affect the timing of actual future net cash flows from proved reserves, and thus their actual present value. In addition, the 10% discount factor used when calculating discounted future net cash flows for financial statement disclosure may not be the most appropriate discount factor based on interest rates in effect from time to time and risks associated with the Company or the oil and natural gas industry in general.

Risks and Uncertainties

The Company operates in an industry that is subject to intense competition and change in consumer demand. The Company's operations are subject to significant risk and uncertainties including financial and operational risks including the potential risk of business failure.

The Company’s future success depends largely on its ability to find and develop or acquire additional oil and gas reserves that are economically recoverable. Unless the Company replaces the reserves produced through successful development, exploration or acquisition activities, proved reserves will decline over time. Recovery of any additional reserves will require significant capital expenditures and successful drilling operations. The Company may not be able to successfully find and produce reserves economically in the future. In addition, the Company may not be able to acquire proved reserves at acceptable costs.

Cash and Cash Equivalents

The Company considers all highly liquid instruments purchased with an original maturity of three months or less to be cash equivalents. There were no cash equivalents at December 31, 2014 and 2013.

The Company minimizes its credit risk associated with cash by periodically evaluating the credit quality of its primary financial institution. The balance at times may exceed federally insured limits.

Accounts Receivable and Allowance for Doubtful Accounts

Accounts receivable consist primarily of oil and gas receivables, net of a valuation allowance for doubtful accounts. As of December 31, 2014 and 2013, the allowance for doubtful accounts was $0.

Oil and Gas Properties, Successful Efforts Method

The Company accounts for oil and gas properties by the successful efforts method. Under this method of accounting, costs to acquire mineral interests in oil and gas properties, to drill and equip exploratory wells that find proved reserves, and to drill and equip development wells are capitalized. Costs to drill exploratory wells that do not find proved reserves, geological and geophysical costs, and costs of carrying and retaining unproved properties are expensed as incurred. The Company evaluates its proved oil and gas properties for impairment on a field-by-field basis whenever events or changes in circumstances indicate that an asset’s carrying value may not be recoverable. The Company follows FASB ASC 360 - Property, Plant, and Equipment, for these evaluations. Unamortized capital costs are reduced to fair value if the undiscounted future net cash flows from our interest in the property’s estimated proved reserves are less than the asset’s net book value. During the year ended December 31, 2014 and 2013, the Company recorded impairments on oil and gas assets of $3,697,924 and $753,865, respectively.

The costs of development wells are capitalized whether productive or non-productive. Leasehold acquisition costs are capitalized when incurred. If proved reserves are found on an unproved property, leasehold cost is transferred to proved properties. Exploration dry holes are charged to expense when it is determined that no commercial reserves exist. Other exploration costs, including personnel costs, geological and geophysical expenses and delay rentals for oil and gas leases, are charged to expense when incurred. The costs of acquiring or constructing support equipment and facilities used in oil and natural gas producing activities are capitalized. Production costs are charged to expense as incurred and are those costs incurred to operate and maintain the Company’s wells and related equipment and facilities.

Depletion of producing oil and gas properties is recorded based on units of production. Acquisition costs of proved properties are depleted on the basis of all proved reserves, developed and undeveloped, and capitalized development costs (wells and related equipment and facilities) are depleted on the basis of proved developed reserves. As more fully described below, proved reserves are estimated by the Company’s independent petroleum engineer and are subject to future revisions based on availability of additional information. Asset retirement costs are recognized when the asset is placed in service, and are depleted over proved reserves using the units of production method.

Oil and gas properties are reviewed for impairment when facts and circumstances indicate that their carrying value may not be recoverable. The Company compares net capitalized costs of proved oil and gas properties to estimated undiscounted future net cash flows using management’s expectations of future oil and natural gas prices. These future price scenarios reflect the Company’s estimation of future price volatility. If net capitalized costs exceed estimated undiscounted future net cash flows, the measurement of impairment is based on estimated fair value, using estimated discounted future net cash flows based on management’s expectations of future oil and natural gas prices.

Unproven properties that are individually significant are assessed for impairment and if considered impaired are charged to expense when such impairment is deemed to have occurred. We perform periodic assessment of individually significant unproved crude oil and gas properties for impairment on a quarterly basis and we would recognize a loss at the time if there was an impairment by providing an impairment allowance. In determining whether a significant unproved property is impaired we consider numerous factors including, but not limited to, current exploration plans, favorable or unfavorable exploratory activity on adjacent leaseholds, our management and geologists’ evaluation of the lease, and the remaining months in the lease term. As of December 31, 2014 and 2013, the Company does not have unproved properties whose acquisition costs are not significant. Thus, all unproven properties were assessed for impairment and the Company recorded an impairment allowance for expiring leases for the years ended December 31, 2014 and 2013.

The sale of a partial interest in a proved oil and gas property is accounted for as normal retirement and no gain or loss is recognized as long as this treatment does not significantly affect the units-of-production depletion rate. If the units-of-production rate is significantly affected, then the sale shall be accounted for as the sale of an asset, and a gain or loss shall be recognized. The unamortized cost of the property or group of properties shall be apportioned to the interest sold and the interest retained on the basis of the fair values of those interests. A gain or loss is recognized for all other sales of producing properties and is included in the results of operations. The sale of a partial interest in an unproved property is accounted for as a recovery of cost when substantial uncertainty exists as to recovery of the cost applicable to the interest retained. A gain on the sale is recognized to the extent the sales price exceeds the carrying amount of the unproved property. A gain or loss is recognized for all other sales of nonproducing properties and is included in the results of operations.

Support Facilities and Equipment

Support facilities and equipment include property and equipment that are not oil and gas properties and are recorded at cost and depreciated using the straight-line method over their estimated useful lives of five to ten years. Expenditures for replacements, renewals, and betterments are capitalized. Maintenance and repairs are charged to operations as incurred. Long-lived assets, other than oil and gas properties, are evaluated for impairment to determine if current circumstances and market conditions indicate the carrying amount may not be recoverable. Our support facilities and equipment are generally located in proximity to certain of our principal fields.

Proved Reserves

Estimates of the Company’s proved reserves included in this report are prepared in accordance with U.S. GAAP and guidelines from the SEC. The Company’s engineering estimates of proved oil and natural gas reserves directly impact financial accounting estimates, including depreciation, depletion and amortization expense and impairment. Proved oil and natural gas reserves are the estimated quantities of oil and natural gas reserves that geological and engineering data demonstrate with reasonable certainty to be recoverable in future years from known reservoirs under period-end economic and operating conditions. The process of estimating quantities of proved reserves is very complex, requiring significant subjective decisions in the evaluation of all geological, engineering and economic data for each reservoir. The accuracy of a reserve estimate is a function of: (i) the quality and quantity of available data; (ii) the interpretation of that data; (iii) the accuracy of various mandated economic assumptions; and (iv) the judgment of the persons preparing the estimate. The data for a given reservoir may change substantially over time as a result of numerous factors, including additional development activity, evolving production history and continual reassessment of the viability of production under varying economic conditions. Changes in oil and natural gas prices, operating costs and expected performance from a given reservoir also will result in revisions to the amount of the Company’s estimated proved reserves. The Company engages independent reserve engineers to estimate its proved reserves.

Asset Retirement Obligations

The Company follows the provisions of the FASB ASC 410 - Asset Retirement and Environmental Obligations. The fair value of an asset retirement obligation is recognized in the period in which it is incurred if a reasonable estimate of fair value can be made. As of December 31, 2014 and 2013, the Company’s obligations were $639,349 and $34,000, respectively. The present value of the estimated asset retirement costs is capitalized as part of the carrying amount of the long-lived asset. The Company’s asset retirement obligations relate to the abandonment of oil and gas producing facilities. The amounts recognized are based upon numerous estimates and assumptions, including future retirement costs, future recoverable quantities of oil and gas, future inflation rates and the credit-adjusted risk-free interest rate. Accretion of asset retirement costs were immaterial for the years ended December 31, 2014 and 2013.

Debt Issue Costs and Debt Discount

The Company may pay debt issue costs, and record debt discounts in connection with raising funds through the issuance of convertible debt. These costs are amortized over the life of the debt to interest expense. If a conversion of the underlying debt occurs, a proportionate share of the unamortized amounts is immediately expensed.

Original Issue Discount

For certain debt issued the Company provided the debt holder with an original issue discount. The original issue discount was equal to simple interest at 10% -20% of the proceeds raised. The original issue discount was recorded to debt discount reducing the face amount of the note and is being amortized to interest expense over the maturity period of the debt. For certain debt the original issue discount exceeded face value bringing the carrying value to $0 and the remainder charged to interest expense.

Beneficial Conversion Feature

For conventional convertible debt where the rate of conversion is below market value, the Company records a “beneficial conversion feature” (“BCF”) and related debt discount.

When the Company records a BCF the relative fair value of the BCF would be recorded as a debt discount against the face amount of the respective debt instrument. The debt discount attributable to the BCF is amortized over the period from issuance to the date that the debt matures.

Derivative Financial Instruments

Fair value accounting requires bifurcation of embedded derivative instruments such as ratchet provisions or conversion features in convertible debt or equity instruments, and measurement of their fair value for accounting purposes. In determining the appropriate fair value, the Company utilized an option pricing model. In assessing the Company’s convertible debt instruments, management determines if the convertible debt host instrument is conventional convertible debt and further if there is a beneficial conversion feature requiring measurement. If the instrument is not considered conventional convertible debt, the Company will continue its evaluation process of these instruments as derivative financial instruments.

Once determined, the derivative liabilities are adjusted to reflect fair value at each reporting period end, with any increase or decrease in the fair value being recorded in results of operations as an adjustment to fair value of derivatives. In addition, the fair value of freestanding derivative instruments such as warrants, are also valued using the option pricing model.

Revenue Recognition

Revenues from the sale of oil and natural gas are recognized when the product is delivered at a fixed or determinable price, title has transferred, and collectability is reasonably assured and evidenced by a contract. The Company follows the “sales method” of accounting for oil and natural gas revenue, so it recognizes revenue on all natural gas or crude oil sold to purchasers, regardless of whether the sales are proportionate to its ownership in the property. A receivable or liability is recognized only to the extent that the Company has an imbalance on a specific property greater than its share of the expected remaining proved reserves.

Share-Based Payments

Generally, all forms of share-based payments, including stock option grants, warrants, restricted stock grants and stock appreciation rights are measured at their fair value utilizing an option pricing model on the awards’ grant date, based on the estimated number of awards that are ultimately expected to vest. Share-based compensation awards issued to non-employees for services rendered are recorded at either the fair value of the services rendered or the fair value of the share-based payment, whichever is more readily determinable. The expenses resulting from share-based payments are recorded in cost of goods sold or general and administrative expense in the statement of operations, depending on the nature of the services provided.

Income Taxes

The Company is a taxable entity and recognizes deferred tax assets and liabilities 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 be in effect when the temporary differences reverse. The effect on the deferred tax assets and liabilities of a change in tax rates is recognized in income in the year that includes the enactment date of the rate change. A valuation allowance is used to reduce deferred tax assets to the amount that is more likely than not to be realized. Interest and penalties associated with income taxes are included in selling, general and administrative expense.

The Company follows ASC 740 “Accounting for Uncertainty in Income Taxes” which prescribes a comprehensive model of how a company should recognize, measure, present, and disclose in its consolidated financial statements uncertain tax positions that the Company has taken or expects to take on a tax return. ASC 740 states that a tax benefit from an uncertain position may be recognized if it is "more likely than not" that the position is sustainable, based upon its technical merits. The tax benefit of a qualifying position is the largest amount of tax benefit that is greater than 50 percent likely of being realized upon ultimate settlement with a taxing authority having full knowledge of all relevant information. After review of the Company’s tax positions, no liabilities were recorded for unrecognized tax benefits as of December 31, 2014 or December 31, 2013.

Earnings Per Share

Basic earnings (loss) per share is computed by dividing net income (loss) by the weighted average number of shares of common stock outstanding during each period. Diluted earnings (loss) per share is computed by dividing net income (loss), adjusted for changes in income or loss that resulted from the assumed conversion of convertible shares, by the weighted average number of shares of common stock, common stock equivalents and potentially dilutive securities outstanding during the period.

The Company had the following potential common stock equivalents at December 31, 2014:

Convertible debt – face amount of $21,657,939, conversion price of $0.25 - $2.50			73,782,461
Common stock options, exercise price of $0.08 - $0.50			15,225,000
Common stock warrants, exercise price of $0.15 - $5.00			33,450,677
Total common stock equivalents			122,458,138

The Company had the following potential common stock equivalents at December 31, 2013:

Convertible debt – face amount of $216,000, conversion price of $0.70			308,571
Common stock options, exercise price of $0.08 - $0.50			8,975,000
Common stock warrants, exercise price of $0.15 - $0.85			9,306,250
Common stock to be issued			2,770,000
Total common stock equivalents			21,359,821

Since the Company reflected a net loss in 2014 and 2013, the effect of considering any common stock equivalents, would have been anti-dilutive. A separate computation of diluted earnings (loss) per share is not presented.

Fair Value of Financial Instruments

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 at the measurement date (exit price). The Company utilizes market data or assumptions that market participants would use in pricing the asset or liability, including assumptions about risk inherent in the inputs to the valuation technique. The authoritative guidance establishes a fair value hierarchy that prioritizes the inputs used to measure fair value. The hierarchy gives the highest priority to unadjusted quoted prices in active markets for identical assets or liabilities (Level 1 measurements) and the lowest priority to unobservable inputs (Level 3 measurements).

The three levels of the fair value hierarchy are as follows:

Level 1	Quoted market prices available in active markets for identical assets or liabilities as of the reporting date.

Level 2	Pricing inputs other than quoted prices in active markets included in Level 1, which are either directly or indirectly observable as of the reporting date.

Level 3	Pricing inputs that are generally unobservable inputs and not corroborated by market data.

Financial assets and liabilities are considered Level 3 when their fair values are determined using pricing models, discounted cash flow methodologies or similar techniques and at least one significant model assumption or input is unobservable.

The fair value hierarchy gives the highest priority to quoted prices (unadjusted) in active markets for identical assets or liabilities and the lowest priority to unobservable inputs. If the inputs used to measure the financial assets and liabilities fall within more than one level described above, the categorization is based on the lowest level input that is significant to the fair value measurement of the instrument.

The carrying amounts of the Company’s financial assets and liabilities, such as cash, prepaid expenses and other current assets, accounts payable and accrued liabilities approximate their fair values because of the short maturity of these instruments.

The Company’s Level 3 financial liabilities consist of the derivative warrants issued with the 2011 notes payables for which there is no current market for this security such that the determination of fair value requires significant judgment or estimation. The Company valued the reset adjustments in the warrant on subsequent potential equity offerings using an option pricing model, for which management understands the methodologies. These models incorporate transaction details such as the Company’s stock price, contractual terms, maturity, risk-free rates, as well as assumptions about future financings, volatility, and holder behavior as of the date of issuance and each balance sheet date.

Transactions involving related parties cannot be presumed to be carried out on an arm's-length basis, as the requisite conditions of competitive, free-market dealings may not exist. Representations about transactions with related parties, if made, shall not imply that the related party transactions were consummated on terms equivalent to those that prevail in arm's-length transactions unless such representations can be substantiated.

The Company uses Level 3 of the fair value hierarchy to measure the fair value of the derivative liabilities and revalues its derivative warrant liability at every reporting period and recognizes gains or losses in the statements of operations attributable to the change in the fair value of the derivatives.

Financial instruments measured at fair value on a recurring basis are summarized below and disclosed on the balance sheets as follows:

December 31, 2014	Fair Value Measurement Using
	Level 1		Level 2		Level 3		Total
Derivative warrant liabilities	$	-	$	-	$	128,829	$	128,829

December 31, 2013	Fair Value Measurement Using
	Level 1		Level 2		Level 3		Total
Derivative warrant liabilities	$	-	$	-	$	76,675	$	76,675

The table below provides a summary of the changes in fair value, including net transfers in and/or out, of all financial instruments measured at fair value on a recurring basis using significant unobservable inputs (Level 3) during the period January 1, 2012 to December 31, 2013:

	Fair Value Measurement Using Level 3 Inputs
	Derivative Liabilities			Total

Balance, January 1, 2013	$	593,555		$	593,555

Purchases, issuances and settlements		-			-

Total gains or losses (realized/unrealized) included in net loss		(516,880	)		(516,880	)

Transfers in and/or out of Level 3		-			-

Balance, December 31, 2013	$	76,675		$	76,675

Purchases, issuances and settlements

Total gains or losses (realized/unrealized) included in net loss		52,154	52,154

Transfers in and/or out of Level 3

Balance, December 31, 2014	$	128,829	128,829

Fair Value of Financial Assets and Liabilities Measured on a Non-Recurring Basis

For periods in which impairment charges have been incurred, the Company is required to write down the value of the impaired asset to its estimated fair value. The initial measurement of these assets at fair value is calculated using discounted cash flow techniques and based on estimates of future revenues and costs. Significant Level 3 assumptions associated with the calculation of discounted cash flows used in the impairment analysis include the Company’s estimate of future crude oil and natural gas prices, production costs, development expenditures, and anticipated production of proved and probable reserves, appropriate risk-adjusted discount rates and other relevant data. The Company recorded total impairment losses of $4,740,899 and $753,865 for the years ended December 31, 2014 and 2013, respectively.

Jumpstart Our Business Startups Act (“JOBS Act”), adopted January 3, 2012

We qualify as an “emerging growth company,” as defined in Section 2(a) of the Securities Act as modified by the Jumpstart Our Business Startups Act of 2012 (the “JOBS Act”). As such, we are permitted to rely on exemptions from various reporting requirements including, but not limited to, the requirement to comply with the auditor attestation requirements of Section 404(b) of the Sarbanes–Oxley Act of 2002, and the requirement to submit certain executive compensation matters to shareholder advisory votes such as “say on pay” and “say on frequency.”

In addition, Section 107 of the JOBS Act also provides that an “emerging growth company” can take advantage of the extended transition period provided in Section 7(a)(2)(B) of the Securities Act for complying with new or revised accounting standards. In other words, an “emerging growth company” can delay the adoption of certain accounting standards until those standards would otherwise apply to private companies. We have elected to take advantage of the benefits of this extended transition period. Our financial statements may therefore not be comparable to those of companies that comply with such new or revised accounting standards.

We will remain an emerging growth company up to the fifth anniversary of our first registered sale of common equity securities, or until the earliest of (a) the last day of the first fiscal year in which our annual gross revenues exceed $1 billion, (b) the date that we become a “large accelerated filer” as defined in Rule 12b-2 under the Exchange Act, which would occur if the market value of our common stock held by non-affiliates exceeds $700 million as of the last business day of our most recently completed second fiscal quarter, or (c) the date on which we have issued more than $1 billion in non-convertible debt during the preceding three-year period.

Recent Accounting Pronouncements

From time to time, new accounting pronouncements are issued by the FASB that are adopted by the Company as of the specified effective date. If not discussed, management believes that the impact of recently issued standards, which are not yet effective, will not have a material impact on the Company’s financial statements upon adoption.

In May 2014, the Financial Accounting Standards Board issued accounting guidance on revenue recognition. The amended guidance will enhance the comparability of revenue recognition practices and will be applied to all contracts with customers. Improved disclosures related to the nature, amount, timing, and uncertainty of revenue that is recognized are requirements under the amended guidance. This guidance will be effective for fiscal 2017 and will be required to be applied retrospectively. We are currently assessing the impact that this guidance will have on our financial statements at this time.

In August 2014, the Financial Accounting Standards Board issued ASU No. 2014-15. This standard provides guidance on determining when and how to disclose going-concern uncertainties in the financial statements. The new standard requires management to perform interim and annual assessments of an entity’s ability to continue as a going concern within one year of the date the financial statements are issued. This ASU is effective for fiscal years, and interim periods within those years, beginning on or after December 15, 2016, with early adoption permitted. The Company is evaluating the new guidance and plans to provide additional information about its expected impact at a future date.

In April 2015, the Financial Accounting Standards Board issued ASU No. 2015-03. This standard provides guidance on the balance sheet presentation for debt issuance costs and debt discounts and debt premiums. To simplify the presentation of debt issuance costs, this standard requires that debt issuance costs related to a recognized debt liability be presented in the balance sheet as a direct deduction from the carrying amount of that debt liability. This ASU is effective for fiscal years beginning after December 15, 2015. The Company is evaluating the new guidance and plans to provide additional information about its expected impact at a future date.

Stratex Oil & Gas Holdings, Inc. 10-K/A