10-Q

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q

x QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the quarterly period ended December 31, 2013

OR

¨ TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

Commission File Number: 001-33578

Samson Oil & Gas Limited

(Exact Name of Registrant as Specified in its Charter)

Australia	N/A
(State or Other Jurisdiction of Incorporation or Organization)	(I.R.S. Employer Identification No.)

Level 16, AMP Building, 140 St Georges Terrace Perth, Western Australia 6000
(Address Of Principal Executive Offices)	(Zip Code)

+61 8 9220 9830

(Registrant’s Telephone Number, Including Area Code)

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days.   x Yes     ¨   No

Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files). Yes x      No ¨

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, or a smaller reporting company. See the definitions of “large accelerated filer,” “accelerated filer” and “smaller reporting company” in Rule 12b-2 of the Exchange Act.

Large accelerated filer	¨	Accelerated filer     x
Non-accelerated filer	¨	Smaller reporting company     ¨

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act).  Yes ¨ No x

There were 2,547,627,193 ordinary shares outstanding as of February 6, 2014.

1

Table of Contents

SAMSON OIL & GAS LIMITED

FORM 10-Q

QUARTER ENDED DECEMBER 31, 2013

TABLE OF CONTENTS

		Page
Part I — Financial Information		3
Item 1.	Financial Statement (unaudited)	3
	Consolidated Balance Sheets, December 31, 2013 and June 30, 2013	4
	Consolidated Statement of Operations and Comprehensive Income (Loss) for the three months and six months ended December 31, 2013 and 2012	5
	Consolidated Statement of Changes in Stockholders’ Equity for the six months ended December 31, 2013	6
	Consolidated Statement of Cash Flows for the six months ended December 31, 2013 and 2012	7
	Notes to  Consolidated Financial Statements (unaudited)	8
Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations.	14
Item 3.	Quantitative and Qualitative Disclosures About Market Risk.	22
Item 4.	Controls and Procedures.	22
Part II   — Other Information		23
Item 1.	Legal Proceedings.	23
Item 1A.	Risk Factors.	23
Item 2.	Unregistered Sales of Equity Securities and Use of Proceeds.	23
Item 3.	Defaults Upon Senior Securities.	23
Item 4.	Mine Safety Disclosures	23
Item 5.	Other Information.	23
Item 6.	Exhibits.	24
Signatures		25

i

Table of Contents

 FORWARD-LOOKING STATEMENTS

Written forward–looking statements may appear in documents filed with the Securities and Exchange Commission (“SEC”), including this quarterly report, documents incorporated by reference, reports to shareholders and other communications.

The U.S. Private Securities Litigation Reform Act of 1995 provides a “safe harbor” for forward–looking information to encourage companies to provide prospective information about themselves without fear of litigation so long as the information is identified as forward looking and is accompanied by meaningful cautionary statements identifying important factors that could cause actual results to differ materially from those projected in the information. Samson relies on this safe harbor in making forward–looking statements.

Forward–looking statements appear in a number of places in this quarterly report and include but are not limited to management’s comments regarding business strategy, exploration and development drilling prospects and activities at our oil and gas properties, oil and gas pipeline availability and capacity, natural gas and oil reserves and production, meeting our capital raising targets and following any use of proceeds plans, our ability to and methods by which we may raise additional capital, production and future operating results.

In this quarterly report, the use of words such as “anticipate,” “continue,” “estimate,” “expect,” “likely,” “may,” “will,” “project,” “should,” “believe” and similar expressions are intended to identify uncertainties. While we believe that the expectations reflected in those forward–looking statements are reasonable, we cannot assure you that these expectations will prove to be correct. Our actual results could differ materially from those anticipated in these forward–looking statements. The differences between actual results and those predicted by the forward-looking statements could be material. Forward-looking statements are based upon our expectations relating to, among other things:

· our future financial position, including cash flow, anticipated liquidity, outcome of capital raising efforts, and debt levels;

· the timing, effects and success of our exploration and development activities;

· our ability to find, acquire, market, develop and produce new properties and dispose of properties;

· uncertainties in the estimation of proved reserves and in the projection of future rates of production;

· timing, amount, and marketability of production;

· third party operational curtailment, processing plant or pipeline capacity constraints beyond our control;

· declines in the values of our properties that may result in write-downs;

· effectiveness of management strategies and decisions;

· the strength and financial resources of our competitors;

· oil and natural gas prices and demand;

· our entrance into transactions in commodity derivative instruments;

· climatic conditions;

· the receipt of governmental permits and other approvals relating to our operations;

· unanticipated recovery or production problems, including cratering, explosions, fires; and

· uncontrollable flows of oil, gas or well fluids.

Many of these factors are beyond our ability to control or predict. Neither these factors nor those included in the “Risk Factors” section of this quarterly report represent a complete list of the factors that may affect us.  We do not undertake to update the forward–looking statements made in this report.

2

Part I — Financial Information

Item 1.   Financial Statements.

  SAMSON OIL & GAS LIMITED AND SUBSIDIARIES

 CONSOLIDATED BALANCE SHEETS

(Unaudited)

	31-Dec-13			30-Jun-13
ASSETS
CURRENT ASSETS
Cash and cash equivalents	$	5,902,559		$	13,170,627
Restricted Cash		722,680			-
Accounts receivable, net of allowance for doubtful accounts of $nil and $nil respectively		2,716,219			3,090,666
Prepayments		5,103,646			411,113
Pipe inventory – held by third party		-			78,944
Income tax receivable		778,175			777,804
Total current assets		15,223,279			17,529,154
PROPERTY, PLANT AND EQUIPMENT, AT COST
Oil and gas properties, successful efforts method of accounting, less accumulated depreciation, depletion and impairment of $19,270,685and $18,318,918at December 31, 2013 and June 30, 2013, respectively.		25,521,914			19,992,018
Other property and equipment, net of accumulated depreciation and amortization of $406,232 and $351,037 at December 31, 2013 and June 30, 2013, respectively		336,506			367,657
Net property, plant and equipment		25,858,420			20,359,675
OTHER ASSETS
Undeveloped capitalized acreage		12,369,412			12,369,412
Capitalized exploration expense		2,771,794			2,468,934
Other		94,019			79,490
TOTAL ASSETS	$	56,316,924		$	52,806,665
LIABILITIES AND STOCKHOLDERS’ EQUITY
CURRENT LIABILITIES
Accounts payable	$	1,716,978		$	1,381,407
Accruals		2,599,603			5,406,982
Provision for annual leave		281,219			242,368
Total current liabilities		4,597,800			7,030,757
Asset retirement obligations		1,048,001			868,589
TOTAL LIABILITIES		5,645,801			7,899,346
STOCKHOLDERS’ EQUITY – nil par value
2,547,627,193 (equivalent to 127,381,360 ADR’s) and 2,229,165,163 (equivalent to 111,452,258 ADR’s)  ordinary shares issued and outstanding at December 31, 2013 and June 30, 2013, respectively		99,580,273			92,717,784
Accumulated other comprehensive income		1,400,195			1,978,250
Accumulated deficit		(50,309,345	)		(49,788,715	)
Total stockholders’ equity		50,671,123			44,907,319
TOTAL LIABILITIES AND STOCKHOLDERS’ EQUITY	$	56,316,924		$	52,806,665

See accompanying Notes to Consolidated Financial Statements.

3

SAMSON OIL & GAS LIMITED AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF OPERATIONS AND COMPREHENSIVE INCOME (LOSS)

(Unaudited)

	Three months ended						Six months ended
	31-Dec-13			31-Dec-12			31-Dec-13			31-Dec-12
REVENUES AND OTHER INCOME:
Oil sales	$	1,082,154		$	1,457,238		$	2,339,144		$	2,903,775
Gas sales		202,658			218,885			344,604			364,907
Other liquids		627			0			627			4,199
Interest income		86,853			55,139			101,298			126,779
Gain on sale of oil and gas properties		-			-			2,524,411			-
Other		85			111,469			184			111,481
TOTAL REVENUE AND OTHER INCOME		1,372,377			1,842,731			5,310,268			3,511,141
EXPENSES:
Lease operating expense		(586,926	)		(1,041,761	)		(1,231,676	)		(1,853,750	)
Depletion, depreciation and amortization		(417,723	)		(498,851	)		(881,805	)		(1,089,618	)
Impairment expense		-			(244,560	)		(83,121	)		(244,589	)
Exploration and evaluation expenditure		(51,669	)		(39,006	)		(319,374	)		(400,950	)
Accretion of asset retirement obligations		(17,117	)		(13,675	)		(32,813	)		(27,109	)
General and administrative		(1,679,066	)		(1,336,332	)		(3,282,109	)		(2,819,114	)
TOTAL EXPENSES		(2,752,501	)		(3,174,185	)		(5,830,898	)		(6,435,130	)
Income/(loss) from operations		(1,380,124	)		(1,331,454	)		(520,630	)		(2,923,989	)
Income tax benefit		-			1,366,938			-			2,035,936
Net income/(loss)		(1,380,124	)		35,484			(520,630	)		(888,053	)
OTHER COMPREHENSIVE GAIN (LOSS)
Foreign currency translation gain (loss)		(383,280	)		(62,606	)		(578,055	)		89,070
Total comprehensive gain/(loss) for the period	$	(1,763,404	)	$	(27,122	)	$	(1,098,685	)	$	(798,983	)
Net gain/(loss) per ordinary share from operations:
Basic – cents per share		(0.05	)		0.00			(0.02	)		(0.05	)
Diluted – cents per share		(0.05	)		0.00			(0.02	)		(0.05	)
Weighted average ordinary shares outstanding:
Basic		2,547,627,193			1,832,852,723			2,452,931,137			1,808,716,468
Diluted		2,547,627,193			1,955,132,196			2,452,931,137			1,808,716,468

See accompanying Notes to Consolidated Financial Statements.

4

SAMSON OIL & GAS LIMITED AND SUBSIDIARIES

CONSOLIDATED STATEMENT OF CHANGES IN STOCKHOLDERS’ EQUITY

(Unaudited)

	Ordinary						Accumulated Other			Total
	Shares			(Accumulated Deficit)			Other			Stockholders's
							Comprehensive			Equity
							Income
Balance at June 30, 2013	$	92,717,784		$	(49,788,715	)	$	1,978,250		$	44,907,319
Net income		-			(520,630	)		-			(520,630	)
Foreign currency translation (loss), net of tax of $nil		-			-			(578,055	)		(578,055	)
Total comprehensive income/(loss) for the period		-			(520,630	)		(578,055	)		(1,098,685	)
Stock based compensation		86,244			-			-			86,244
Issue of share capital		7,337,485			-			-			7,337,485
Share issuance costs		(561,240	)		-			-			(561,240	)
Balance at December 31, 2013	$	99,580,273		$	(50,309,345	)	$	1,400,195		$	50,671,123

See accompanying Notes to Consolidated Financial Statements.

5

SAMSON OIL & GAS LIMITED AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF CASH FLOWS

(Unaudited)

	Six months ended
	31-Dec-13			31-Dec-12
Cash flows used in operating activities
Receipts from customers	$	2,504,828		$	3,487,463
Payments to suppliers & employees		(4,207,411	)		(4,464,795	)
Interest received		102,019			138,544
Income tax paid		-			(100	)
Net cash flows used in operating activities		(1,600,564	)		(838,888	)
Cash flows used in investing activities
Proceeds from sale of oil and gas properties		3,547,409			-
Payments for plant & equipment		(25,041	)		(10,392	)
Payments for exploration and evaluation		(240,945	)		(10,371,563	)
Payments for oil and gas properties		(15,144,169	)		(1,140,341	)
Net cash flows used in investing activities		(11,862,746	)		(11,522,296	)
Cash flows  provided by financing activities
Issuance of share capital		7,337,138			-
Proceeds from the exercise of options		347			3,132,420
Share issuance costs		(561,239	)		-
Net cash flows provided by financing activities		6,776,246			3,132,420
Net decrease in cash and cash equivalents		(6,687,064	)		(9,228,764	)
Cash and cash equivalents at the beginning of the fiscal period		13,170,627			18,845,894
Effects of exchange rate changes on cash and cash equivalents		(581,004	)		108,033
Cash and cash equivalents at end of fiscal period	$	5,902,559		$	9,725,163

See accompanying Notes to Consolidated Financial Statements

6

SAMSON OIL & GAS LIMITED AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

1. Basis of Presentation

These Consolidated Financial Statements have been prepared in accordance with accounting principles generally accepted in the United States of America (GAAP) for interim financial reporting. All adjustments which are normal and recurring by nature, in the opinion of management, necessary for fair statement of Samson Oil & Gas Limited’s (the Company) Consolidated Financial Statements have been included herein. Interim results are not necessarily indicative of expected annual results because of the impact of fluctuations in prices received for oil and natural gas, as well as other factors. In the course of preparing the Consolidated Financial Statements, management makes various assumptions, judgments and estimates to determine the reported amounts of assets, liabilities, revenues and expenses, and in the disclosures of commitments and contingencies. Changes in these assumptions, judgments and estimates will occur as a result of the passage of time and the occurrence of future events, and, accordingly, actual results could differ from amounts previously established.

The Company’s Consolidated Financial Statements have been prepared on a basis consistent with the accounting principles and policies reflected in the Company’s audited financial statements as of and for the year ended June 30, 2013. The year-end Consolidated Balance Sheet presented herein was derived from audited Consolidated Financial Statements, but does not include all disclosures required by GAAP.

These Consolidated Financial Statements should be read in conjunction with our audited Consolidated Financial Statements included in our Annual Report on Form 10-K for the fiscal year ended June 30, 2013.

Accruals.   Accrued liabilities at December 31, 2013 and June 30, 2013 consist primarily of estimates for goods and services received but not yet invoiced.

Prepayments. The components of prepayments for the periods ended December 31, 2013 and June 30, 2013 include cash advanced to the operators of our drilling projects as a prepayment toward future expected drilling operations. As at December 31, 2013 cash had been advanced to the operator of our North Stockyard infill development project for the drilling and/or completion of five wells.

Recent Accounting Standards

There are no new accounting pronouncements that have not been adopted by the Company as of December 31, 2013 that will have a material effect on the Company’s financial statements.

2. Income Taxes

	Three months ended						Six months ended
	31-Dec-13			31-Dec-12			31-Dec-13			31-Dec-12
Income tax benefit/(expense)	$	-		$	1,366,938		$	-		$	2,035,936
Effective tax rate		0.00	%		102.67	%		0.00	%		70.00	%

Due to the Company's history of net operating losses and the uncertainty of future profitable operations, the Company has recorded a full valuation allowance against its deferred tax assets.

The Company has current year losses and available prior year cumulative net operating losses that may be carried forward to reduce taxable income in future years.  The Tax Reform Act of 1986 contains provisions that limit the utilization of net operation loss carryforwards if there has been a change in ownership as described in Internal Revenue Code Section 382.  The Company’s prior year losses are limited by IRC Section 382, however current year losses are not subject to these limitations.

In the tax year ended June 30, 2012, the Company had a taxable loss of $33 million which exceeded the amount of taxable income, after NOL, generated in the tax year ended June 30, 2011. As a result the loss from June 30, 2012 was carried back to the income year of June 30, 2011 generating a refund of tax paid in that year. As such the balance of the June 30, 2013 losses will be carried forward along with a portion of the current year prior loss to offset future taxable income.

During the quarter ending March 31, 2013, the Company received a $5.6 million income tax refund from the Internal Revenue Service of the taxes paid in a prior period noted above. $0.8 million remains as receivable in the Balance Sheet and is expected to be received within the current year.

7

ASC Topic 740 requires that a valuation allowance be provided if it is more likely than not that some portion or all deferred tax assets will not be realized. The Company’s ability to realize the benefits of its deferred tax assets will depend on the generation of future taxable income through profitable operations. Due to the Company’s history of losses and the uncertainty of future profitable operations, the Company has recorded a full valuation allowance against its deferred tax assets.

3. Earnings Per Share

Basic earnings (loss) per share is calculated by dividing net earnings (loss) attributable to ordinary shares by the weighted average number of shares outstanding for the period. Under the treasury stock method, diluted earnings per share is calculated by dividing net earnings (loss) by the weighted average number of shares outstanding including all potentially dilutive ordinary shares (which in Samson’s case consists of unexercised stock options). In the event of a net loss, however no potential ordinary shares are included in the calculation of shares outstanding since the impact would be anti-dilutive.  

The following table details the weighted average dilutive and anti-dilutive securities outstanding, which consist of options, for the periods presented:

	Three months ended			Six months ended
		31-Dec-13	31-Dec-12		31-Dec-13	31-Dec-12
Dilutive		-	95,791,227		-	-
Anti–dilutive		300,885,050	72,201,619		261,058,802	261,839,351

8

The following tables set forth the calculation of basic and diluted earnings/(loss) per share:

	Three months ended					Six months ended
	31-Dec-13			31-Dec-12		31-Dec-13			31-Dec-12
Net income (loss)	$	(1,380,124	)		35,484	$	(520,630	)		(888,053	)
Basic weighted average ordinary shares outstanding		2,547,627,193			1,832,852,723		2,452,931,137			1,808,716,468
Add: dilutive effect of stock options		-			95,791,227		-			-
Add: bonus element for rights issue		-			26,488,246		-			-
Diluted weighted average ordinary shares outstanding		2,547,627,193			1,955,132,196		2,452,931,137			1,808,716,468
Basic earnings per ordinary share – cents per share		(0.05	)		0.00		(0.02	)		(0.05	)
Diluted earnings per ordinary share – cents per share		(0.05	)		0.00		(0.02	)		(0.05	)

4. Asset Retirement Obligations

The Company’s asset retirement obligations primarily represent the estimated present value of the amounts expected to be incurred to plug, abandon and remediate producing and shut–in properties at the end of their productive lives in accordance with applicable state and federal laws. The Company determines the estimated fair value of its asset retirement obligations by calculating the present value of estimated cash flows related to plugging and abandonment liabilities. The significant inputs used to calculate such liabilities include estimates of costs to be incurred, the Company’s credit adjusted discount rates, inflation rates and estimated dates of abandonment. The asset retirement liability is accreted to its present value each period and the capitalized asset retirement cost is depleted using the units–of–production method.

During the three months ended September 31, 2013, we recorded an out-of-period adjustment to increase our asset retirement obligations by $0.15 million, capitalized asset retirement costs by $0.085 million, and expensed $0.065 million. Based upon an evaluation of the relevant factors, we concluded that the related impact of this out-of-period adjustment was not material to our consolidated financial statements for any current or prior period.

The following table summarizes the activities for the Company’s asset retirement obligations for the six months ended December 31, 2013 and 2012:

	Six months ended
	31-Dec-13			31-Dec-12
Asset retirement obligations at beginning of period	$	868,589		$	808,572
Liabilities incurred or acquired		154,735			4,691
Liabilities settled		(8,136	)		-
Disposition of properties		-			-
Accretion expense		32,813			27,109
Asset retirement obligations at end of period		1,048,001			840,372
Less: current asset retirement obligations (classified with accounts payable and accrued liabilities)		-			-
Long-term asset retirement obligations	$	1,048,001		$	840,372

Discount rates used to calculate the present value vary depending on the estimated timing of the obligation, but typically range between 4% and 9%.

5. Equity Incentive Compensation

Stock-based compensation is measured at the grant date based on the estimated fair value of the awards with the resulting amount recognized as compensation expense on a straight-line basis over the requisite service period (usually the vesting period).

9

Total compensation cost recognized in the Statements of Operations for the grants under the Company’s equity incentive compensation plans was $80,989 and $72,011 during the three months ended December 31, 2013 and 2012 and $86,244 and $152,061 during the six months ended December 31, 2013 and 2012.

As of December 31, 2013, there was $nil total unrecognized compensation cost related to outstanding stock options.

6. Sale of Oil and Gas Assets

In August 2013, we divested half our equity position in the undeveloped acreage in the North Stockyard project to Slawson Exploration Company Inc. (“Slawson”) for $5.562 million in cash and other consideration while retaining our full interest in the currently producing wells in the North Stockyard field. $0.9 million of the cash portion of the purchase price is subject to the delivery of a useable well bore in Billabong. While work is continuing on this well bore, it had to be suspended to permit other drilling operations to proceed on the same pad. The Billabong work is currently expected to recommence by the end of March 2014. The remaining $4.6 million in consideration was transferred into an escrow account on the sale date, less $0.4 million which was transferred to Slawson as it related to cash calls from other non-operator parties received by Samson prior to the sale. As at December 31, 2013, $3.5 million in sale funds have been released from the escrow account, at the time of the sale. The remaining $0.7 million is recorded as Restricted Cash on the Balance Sheet at December 2013. These funds are expected to be released to us prior the end of the quarter ending March 31, 2014.

As a consequence of the transaction the rig contract with Frontier was also terminated, with no penalty payment. Slawson are now the operator of the project going forward for the development of the undeveloped acreage.

Along with the undeveloped acreage for which a gain on sale was recognized in the Income Statement of $2.52 million, we have also transferred a 25% working interest in the drilled but not yet completed, Sail and Anchor well, as well as a 25% working interest in the salt water disposal well drilled in the prior year in the North Stockyard project for $2.92 million, recognized as a reimbursement in the capitalized costs for these assets on the December 31, 2013 Balance Sheet. 

7. Fair Value Measurements

Fair value is defined as the price that would be received in the sale of 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 and the risks inherent in the inputs to the valuation technique. These inputs can be readily observable, market corroborated, or generally unobservable. The Company classifies fair value balances based on the observability of those inputs. The FASB has established 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 measurement) and the lowest priority to unobservable inputs (level 3 measurement).

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

· Level 1—Quoted prices are available in active markets for identical assets or liabilities as of the reporting date. Active markets are those in which transactions for the asset or liability occur in sufficient frequency and volume to provide pricing information on an ongoing basis.

· Level 2—Pricing inputs are other than quoted prices in active markets included in level 1, but are either directly or indirectly observable as of the reported date and for substantially the full term of the instrument. Inputs may include quoted prices for similar assets and liabilities. Level 2 includes those financial instruments that are valued using models or other valuation methodologies.

· Level 3—Pricing inputs include significant inputs that are generally less observable from objective sources. These inputs may be used with internally developed methodologies that result in management’s best estimate of fair value.

Financial assets and liabilities are classified in their entirety based on the lowest level of input that is significant to the fair value measurement. The Company’s assessment of the significance of a particular input to the fair value measurement requires judgment, and may affect the valuation of fair value assets and liabilities and their placement within the fair value hierarchy levels. The following table sets forth by level within the fair value hierarchy the Company’s financial assets and liabilities that were accounted for at fair value as of December 31, 2013 and June 30, 2013.

	Carrying value at December 31, 2013		Level 1		Level 2		Level 3		Fair Value at December 31, 2013
Assets
Cash and cash equivalents	$	5,902,559	$	5,902,559	$	-	$	-	$	5,902,559
Restricted cash		722,680		722,680		-		-		722,680

10

	Carrying value at June 30, 2013		Level 1		Level 2		Level 3		Fair Value at June 30, 2013
Assets
Cash and cash equivalents	$	13,170,627	$	13,170,627	$	-	$	-	$	13,170,627

The following methods and assumptions were used to estimate the fair value of the assets and liabilities in the table above:

Fair Value of Financial Instruments.   The Company’s financial instruments consist primarily of cash and cash equivalents, restricted cash, accounts receivable and payable and derivatives (discussed below). The carrying values of cash equivalents and accounts receivable and payable are representative of their fair values due to their short–term maturities.

Assets and Liabilities Measured at Fair Value on a Nonrecurring Basis.   The Company also applies fair value accounting guidance to measure non–financial assets and liabilities such as business acquisitions, proved oil and gas properties, and asset retirement obligations. These assets and liabilities are subject to fair value adjustments only in certain circumstances and are not subject to recurring revaluations. These items are primarily valued using the present value of estimated future cash inflows and/or outflows. Given the unobservable nature of these inputs, they are deemed to be Level 3.

8. Commitments and Contingencies

Environmental Matters

The Environmental Protection Agency has proposed a cash settlement of $60,000 in relation to a 400 barrel oil spill on the Pierce well site in February 2009. The spill was contained and the area rehabilitated to the satisfaction of the appropriate authorities in 2009. The costs associated with the spill and subsequent remediation were covered by our insurance. The settlement has not yet been paid and is included within the accrual balance on the Balance Sheet.

Other than the matter mentioned above, the Company has no accrued environmental liabilities for its sites, including sites in which governmental agencies have designated the Company as a potentially responsible party, because it is not probable that a loss will be incurred and the minimum cost and/or amount of loss cannot be reasonably estimated. However, due to uncertainties associated with environmental assessment and remediation activities, future expense to remediate the currently identified sites, and sites identified in the future, if any, could be incurred. Management believes, based upon current site assessments, that the ultimate resolution of any matters will not materially affect our results of operations or cashflows.

9. Capitalized Exploration Expense

We use the successful efforts method of accounting for exploration and evaluation expenditure in respect of each area of interest. The application of this policy requires management to make certain estimates and assumptions as to future events and circumstances, in particular the assessment of whether economic quantities of reserves have been found.  Any such estimates and assumptions may change as new information becomes available.

Exploration and evaluation assets are assessed for impairment when facts and circumstances indicate that the carrying amount of an exploration and evaluation asset may exceed its recoverable amount.  When assessing for impairment consideration is given to but not limited to the following:

§ the period for which Samson has the right to explore;

§ planned and budgeted future exploration expenditure;

§ activities incurred during the year; and

§ activities planned for future periods.

If, after having capitalized expenditures under our policy, we conclude that we are unlikely to recover the expenditures through future exploitation, then the relevant capitalized amount will be written off to expense.

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As of December 31, 2013 we had capitalized exploration expenditures of $2.7 million and undeveloped capitalized acreage expenditures of $12.4 million.  This primarily relates to costs in relation to our Hawk Springs, Roosevelt and South Prairie projects.

Our Hawk Springs project, in Goshen County, Wyoming, includes $3.0 million in undeveloped capitalized acreage costs and $1.5 million in capitalized exploration expenditure. The capitalized exploration expenditure includes costs associated with the acquisition of our North Platte 3D seismic data. During the six months ended December 31, 2013, we spent and capitalized $0.3 million on our Bluff Federal well in the Hawk Springs project. This well is expected to be completed by June 2014.

Our Roosevelt project, in Roosevelt County, Montana, includes $7.8 million in undeveloped capitalized acreage costs and $0.3 million in capitalized exploration expenditure. The capitalized exploration expenditure consists of costs associated with well permitting, surface use agreements and other expenses associated with drilling preparation activities. In December 2013, we entered into a seismic and drilling agreement with Momentus Energy Corp, a Canadian exploration and development company based in Calgary. Momentus had committed to the acquisition of approximately 20 squares of 3-D seismic data at no cost to us. Following the acquisition of the seismic data, Momentus had the option to drill a horizontal Bakken well on our acreage at 100% cost to it. Upon Momentus drilling this well, it will have earned the right to 50% of the test well and 50% of our acreage in the Roosevelt project. This farm out is expected to be finalized by March 2014, with the acquisition of the 3-D seismic data to commence shortly after that.

Our South Prairie project in Ward and Renville counties, North Dakota, includes $1.6 million in undeveloped acreage costs and $0.9 million in capitalized exploration expenditure. This expenditure relates to 3-D seismic acquisition costs. We are not the operator of this project. The joint venture is focusing on developing three structural closure prospects (Pubco, Deering, and Birch) along the Prairie Salt edge in the South Prairie 3-D project. The joint venture has approved that the Pubco Prospect will be drilled next on the eastern edge of the South Prairie 3-D seismic survey. We anticipate this well will be drilled before the end of Q2 of calendar year 2014.

Exploration and divestment activities are continuing in all exploration areas. The outcome of these activities remain uncertain and may result in write offs in future periods if the related efforts prove unsuccessful.

10.  Issue of Share Capital

During the three months ended December 31, 2013 there were no issues of ordinary shares.

During the six months ended December 31, 2013, 9,864 Australian 3.8 cent options were exercised for net proceeds of $348. The options were issued in a public rights offering conducted in June 2013.

During the six months ended December 31, 2013 we issued 318,452,166 ordinary shares for 2.5 cents (Australian cents)/2.3 cents (United States cents) for proceeds of $7.3 million. The ordinary shares were issued to investors in the US and Australia.

11. Cash Flow Statement

Reconciliation of net income/(loss) after tax to the net cash flows from operations: 

	Six months ended
	31-Dec-13			31-Dec-12
Net income/(loss) after tax	$	(520,630	)	$	(888,053	)
Depletion, depreciation and amortization		881,805			1,089,618
Stock based compensation		86,244			152,062
Accretion of asset retirement obligation		32,813			27,109
Impairment expense		83,121			244,589
Exploration and evaluation expenditure		319,374			400,950
Gain on sale of oil and gas properties		(2,524,411	)		-
Changes in assets and liabilities:
(Increase)/decrease in receivables		(179,360	)		24,074
(Increase)/decrease in income tax receivable/deferred tax asset		-			(2,036,036	)
Increase/(decrease) in provision for annual leave		38,851			(37,643	)
(Decrease)/Increase in payables		181,629			184,442
NET CASH FLOWS USED IN OPERATING ACTIVITIES	$	(1,600,564	)	$	(838,888	)

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12. Subsequent Events

In January 2014, we entered into a $25 million credit facility with Mutual of Omaha Bank, with an initial borrowing base of $8.0 million, of which $4.0 million has been drawn down. We expect the remaining $4.0 million in borrowing base will be drawn down prior to June 30, 2014 on an as needed basis. Additional increases in the borrowing base, up to the credit facility maximum of $25 million, may be made available to us in the future depending on the value of our reserves in the future. Borrowing base redeterminations are performed by Mutual of Omaha every six months at June and December. We also have the ability to request a borrowing base redetermination at another period, once a year.

The credit facility includes the following covenants, which will be tested on a quarterly basis:

· Current ratio greater than 1

· Debt to EBITDAX (annualized) ratio no greater than 3.5

· Interest coverage ratio minimum of 2.5 to 1.0

While we expect to be in compliance with these covenants based on our current $4.0 million drawdown, if we are not in compliance with the financial covenants in the credit facility, or if we do not receive a waiver from Mutual of Omaha, our debt could become due and payable upon acceleration by Mutual of Omaha. In addition, failure to comply with any of the covenants under our credit facility could adversely affect our ability to fund ongoing operations.

These funds will be used to fund drilling in our North Stockyard project in North Dakota. We expect to fund our remaining capital expenditures for the fiscal year ending June 30, 2014 with cash on hand and cash flow from operations, though we may obtain additional capital via equity finance raisings, further drawdowns of our credit facility (if possible) or another capital raising program or asset sales.

Item 2.   Management’s Discussion and Analysis of Financial Condition and Results of Operations.

The following is management’s discussion and analysis of certain significant factors that have affected aspects of our financial position and the results of operations during the periods included in the accompanying Condensed Financial Statements. You should read this in conjunction with the discussion under “Management's Discussion and Analysis of Financial Condition and Results of Operations” and the audited Financial Statements for the year ended June 30, 2013, included in our Annual Report on Form 10-K and the Consolidated Financial Statements included elsewhere herein.

Throughout this report, a barrel of oil means a stock tank barrel (“STB”).

Overview

We are an independent energy company primarily engaged in the acquisition, exploration, exploitation and development of oil and natural gas properties.  Our strategy is to focus on the exploration, exploitation and development of our major oil plays – the Niobrara, Permian and Pennsylvanian in Goshen County, Wyoming and the Bakken in Williams County, North Dakota and Roosevelt County, Montana.  

Our net oil production was 12,788 barrels of oil for the quarter ended December 31, 2013, compared to 17,744 barrels of oil for the quarter ended December 31, 2012.  The decrease in oil production was due to operational downtime in the North Stockyard field due in part to the shut-in of offset wells to the infill wells being fracced. This was partially offset by a new Sail and Anchor well, coming on line during the quarter ended December 31, 2013. Our net gas production was 42,990 thousand cubic feet (“Mcf”) for the quarter ended December 31, 2013, compared to 51,587 Mcf for the quarter ended December 31, 2012. The decrease in gas production also relates to the operational downtime in out North Stockyard field.

Our net oil production was 25,424 barrels of oil for the six months ended December 31, 2013 compared to 36,626 barrels of oil for the six months ended December 31, 2012. Our net gas production was 80,972 Mcf for the six months ended December 31, 2013 compared to 92,678 Mcf for the six months ended December 31, 2012. The decrease in oil and gas production is due to the natural decline in production associated with these wells and the result of wells being shut in during the period for workovers or while other wells in the same location are being drilled or fracced. Our net gas production was 80,972 Mcf for the six months ended December 31, 2013 compared to 92,678 Mcf for the six months ended December 31, 2012 for similar reasons.

For the six months ended December 31, 2013 and December 30, 2012, we reported a net loss of $0.6 million and a net loss of $0.9 million, respectively. The loss in the current period reflects a $2.5 million gain from the sale of oil and gas properties while the loss in the prior period included an income tax benefit of $2.0 million. See “Results of Operations” below.

In the execution of our strategy, our management is principally focused on economically developing additional reserves of oil and on maximizing production levels through exploration, exploitation and development activities on a cost-effective basis.

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During the six month period ended December 31, 2013, we issued a total of 318,452,166 ordinary shares in a registered direct offering with investors in the US and Australia. The placement raised $7.3 million, before costs. The placement also included options to subscribe for an additional four ordinary shares for each ten ordinary shares subscribed for at an exercise price of A$0.038 per share, with an expiry date of March 31, 2017.

Notable Activities and Status of Material Properties during the Quarter Ended December 31, 2013 and Current Activities

Undeveloped Properties: Exploration Activities

Hawk Springs Project, Goshen County, Wyoming

Cretaceous Niobrara Formation & Permo-Penn Project, Northern D-J Basin

Samson 37.5% to 100% working interest

We have two contiguous areas in the Hawk Springs Project. One of the areas is a joint venture with a private company and is subject to a Halliburton Joint Venture (HJV).

The Defender US33 #2-29H well is pumped intermittently and produced 491 bbls of oil during the quarter.

The Spirit of America US34 #2-29 (the SOA #2) intersected two excellent quality Permian age reservoirs, the 9,300 ft. sand, which appears to be oil saturated and the 9,500 ft. sand which is water saturated. Integrating the well data to the 3-D seismic data shows that an amplitude anomaly (lithology/porosity indicator) is associated with the 9500’ sand indicating a thick and porous reservoir exists everywhere the amplitude is mapped. After further examination of the 3D seismic and additional data, we believe that the likely reason for the lack of oil saturation in the 9500’ sand is that a leak point can be established by a fortuitous juxtaposition of another porous reservoir across a fault that intersects the amplitude anomaly. Because this arrangement in the SOA prospect appears to be unique in the project area, Samson believes that the potential of the remaining two dozen prospects in the project has been re-established, since these prospects do not appear to be affected by any recognized faulting.

The Bluff #1-11 has been drilled to a depth of 1,037 feet with an air-drill rig and surface casing has been set. A larger top-drive rig will drill the remainder of the well when it becomes available to us. The well will test a four-way dip structural closure in the Permian and Pennsylvanian age rocks to a depth of approximately 8,550 feet. The well is located three miles to the northwest of the Spirit of America US34 #2-29 well (SOA #2) and more than 2000’ shallower in depth. The excellent reservoir properties and oil shows seen in the SOA #2 well has allowed Samson to validate the 3-D seismic data and consequently high-grade the Bluff prospect. We are in the process of farming out additional equity in relation to this well. Operations are expected to commence by the end of March 2014.

Roosevelt Project, Roosevelt County, Montana

Mississippian Bakken Formation, Williston Basin

Samson 100% working interest in Australia II & Gretel II wells, 66.7% in any subsequent drilling, depending on the drilling location

We have an interest in approximately 45,000 gross acres (30,000 net acres) in the Roosevelt Project with Fort Peck Energy Co. (“FPEC”) having the remaining 15,000 net acres.

In December 2013, we entered into a seismic and drilling agreement with Momentus Energy Corp, a Canadian exploration and development company based in Calgary. Momentus has committed to acquire approximately 20 squares of 3-D seismic data at no cost to us. Following the acquisition of the seismic data, Momentus has the option to drill a horizontal Bakken well on our acreage at 100% its own cost. Upon Momentus drilling this well, it will have earned the right to 50% of the test well and 50% of our acreage in the Roosevelt project. The program, consisting of 3-D seismic acquisition and the cost of drilling the Bakken well, is valued at approximately $10 million. This farm out is expected to be finalized by March 2014, with the acquisition of the 3-D seismic data to commence shortly after that.

The two Bakken wells that were drilled in 2011and 2012 in the Roosevelt Project have proven to be uneconomic.

South Prairie Project, North Dakota

Mississippian Mission Canyon Formation, Williston Basin

Samson 25% working interest

Samson has a 25% working interest in 25,590 net acres located on the eastern flank of the Williston Basin in North Dakota. The first well of the project, the Matson #3-1 well was drilled and determined to be a dry hole, which will be plugged and abandoned. During the six months ended December 31, 2013, $0.2 million was written off as dry hole expense.

Based on the technical analysis of this result, the forward program will show a preference for structural closures that exist along the salt edge rather than those created by dissolution events further interior to the salt edge. The joint venture is focusing on developing three structural closure prospects (Pubco, Deering, and Birch) along the Prairie Salt edge in the South Prairie 3-D project. The joint venture has approved that the Pubco Prospect will be drilled next on the eastern edge of the South Prairie 3-D seismic survey. We anticipate this well will be drilled before the end of Q2 of calendar year 2014.

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Developed Properties: Drilling Activities

North Stockyard Oilfield, Williams County, North Dakota

Mississippian Bakken Formation, Williston Basin

Bakken & Three Forks infill wells

Samson ~25-30% working interest

On January 1, 2013, we and the operator group negotiated a non-cash acreage swap for the Middle Bakken/First Bench of the Three Forks (MB/TF), whereby we traded certain interests in our undeveloped acres in the Southern Tier for these parties’ undeveloped acres in the Northern Tier. As a result of this acreage swap we owned 64% and 57%, respectively, in the two overlapping 1,280 acre spacing units located in the Northern Tier. Our net production from current producing wells was not affected. In August 2013, we divested half our equity position in the undeveloped acreage in the North Stockyard project to Slawson Exploration Company Inc. (“Slawson”) for $5.562 million in cash and other consideration while retaining our full interest in the currently producing wells in the North Stockyard field. Slawson is now the operator of the Northern Tier acreage.

We have identified 14 infill development wells in this acreage that can be drilled between the existing Bakken wells and in the Three Forks Formation with 160 acre spacing.

The Billabong 2-13-14HBK well (24.86% working interest, subject to the delivery of a useable well bore to Slawson) was drilled in the Middle Bakken Formation but upon cementing the 4 ½ inch production liner, the bottom of the drill string became cemented in the hole. Wash-over operations have been halted while other drilling operations take place on the same pad location. Operations are expected to recommence by the end of March 2014.

The Coopers 2-15-14HBK (27.7% working interest), Tooheys 4-15-15HBK (27.7% working interest) and Little Creature 1-15-14HBK (27.7%) wells have all been drilled. The wells were fracture stimulated during the quarter with flowback operations expected to commence at the end of January 2014. The Blackdog (25.03% working interest) 3-13-14H well was also drilled during the quarter and fracture stimulation operations are expected to commence in February of 2014.

Rainbow Project, Williams County, North Dakota

Mississippian Bakken Formation, Williston Basin

Samson 23% and 52% working interest

A drilling permit for the Rainbow 10-19-18HBK well has been approved and we anticipate drilling our first well during the third quarter of calendar 2014.

In 2013, we acquired 656 acres in a 1255 acre drilling unit and 294 acres in a 1280 drilling unit. Both drilling units are located in the Rainbow Project, Williams County, North Dakota. The Rainbow Project is located in Sections 17, 18, 19 and 20 in T158N R99W.

Samson acquired the net acres in the Rainbow Project from the vendor for this acreage trade and will provide a $1 million carry (10% of expected costs to drill and complete the first well) to the vendor, for the first development well to be drilled in the Rainbow Project. Samson will have the ability, subject to the vendor acquiring additional acres, to acquire a further 407 acres by carrying the vendor for $0.7 million in the second well in the project.

Samson has assessed the project based on offset well data and believes that the project will support 16 wells, 8 in the middle Bakken and 8 in the first bench of the Three Forks. These wells would be expected to be configured as north-south orientated 10,000 foot horizontals.

In the western drilling unit of the acquired acreage, Samson holds a 52% working interest. In the eastern drilling unit, Samson’s interest is 23% but with the option to increase it to 55% in the second tranche.

Other companies owning an interest in the Rainbow Project include Hess, Halcón and Continental.

Developed Properties: Production Activities

North Stockyard Oilfield, Williams County, North Dakota

Mississippian Bakken Formation, Williston Basin

Samson various working interests

We have eight producing wells in the North Stockyard Field. These wells are located in Williams County, North Dakota, in Township 154N Range 99W.

The Harstad #1-15H well (34.5% working interest) was down for 38 days during the quarter and averaged 325 BOPD from the Mississippian Bluell Formation. Cumulative gross oil production to December 31, 2013 is approximately 113 MSTB.

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The Leonard #1-23H well (10% working interest, 37.5% after non-consent penalty) was down for 3.3 days during the quarter. The well averaged 31 BOPD and 34 Mscf/D during the quarter. Cumulative gross production to December 31, 2013 is approximately 113 MSTB and 118 MMscf.

The Gene #1-22H well (30.6% working interest) was down for approximately 12 days during the quarter. The well produced at an average daily rate of 85 BOPD and 204 Mscf/D during the quarter. Cumulative gross production to December 31, 2013 is approximately 161 MSTB and 187 MMscf.

The Gary #1-24H (37% working interest) well was down for 50 days during the quarter mostly due to planned shut in periods while completing the offset wells. The well averaged 70 BOPD and 88 Mscf/D during the quarter. Cumulative gross production to December 31, 2013 is approximately 159 MSTB and 253 MMscf.

The Rodney #1-14H (27% working interest) well was down for 71 days during the quarter due to planned shut in periods while completing the offset wells. The well produced at an average daily rate of 10 BOPD and 9 Mscf/D during the quarter. Cumulative gross production to December 31, 2013 is approximately 119 MSTB and 169 MMscf.

The Earl #1-13H (32% working interest) well was down for 44 days during the quarter due to planned shut in periods while completing the offset wells. The well produced at an average daily rate of 107 BOPD and 38 Mscf/D. Cumulative gross production to December 31, 2013 is approximately 196 MSTB and 282 MMscf.

The Everett #1-15H (26% working interest) well was down for 50 days during the quarter due to planned shut in periods while completing the offset wells. The Everett well produced at an average daily rate of 46 BOPD and 55 Mscf/D during the quarter. Cumulative production to December 31, 2013 is approximately 102 MSTB and 137 MMscf.

The Sail & Anchor 4-13-14HBK well was shut in most of the quarter due to simultaneous drilling operations. The well did produce 10,579 BO over the 26 days it did produce for an average daily rate of 407 BOPD.

Sabretooth Gas Field, Brazoria County Texas

Oligocene Vicksburg Formation, Gulf Coast Basin

Samson 9.375% working interest

Production for the Davis Bintliff #1 well averaged 4.0 MMscf/D and 35 BOPD for the quarter. Cumulative production to December 31, 2013 is approximately 6.7 Bscf and 75 MSTB.

Abercrombie 1-10H well, Richland County, Montana

Mississippian Bakken Formation, Williston Basin

Samson 2.82% working interest

The Abercrombie #1-10H (SSN 2.82% working interest) averaged 41 BOPD and 115 Mscf/D during the quarter. Cumulative production to December 31, 2013 is approximately 56,912 barrels of oil and 131,579 Mscf.

Riva Ridge 6-7-33-56H well, Sheridan County, Montana

Mississippian Bakken Formation, Williston Basin

Samson 0.76% working interest

The Riva Ridge 6-7-33-56H (SSN 0.76% working interest.) well averaged 14 BOPD and 15 Mscf/D during the quarter. Cumulative production to December 31, 2013 is approximately 24,077 barrels of oil and 7,906 Mscf.

All production amounts above indicate gross production, rather than only the production attributable to our respective working interest for each well. See “Results of Operations” below for total production volume attributed to Samson during the quarter.

Results of Operations

For the three months ended December 31, 2013, we reported a net loss of $1.4 million.

For the six months ended December 31, 2013 we reported a net loss of $0.5 million and a net loss of $0.89 million, after income tax benefit of $2.0 million for the six months ended December 31, 2012.

The following table sets forth selected operating data for the three months ended:

	Three months ended
	31-Dec-13		31-Dec-12		30-Sep-13
Production Volume
Oil (Bbls)		12,788		17,744		12,636
Natural gas (Mcf)		42,990		51,587		37,982
BOE (based on one barrel of oil to six Mcf of natural gas)		19,953		26,342		18,966
Sales Price
Oil ($/Bbls)	$	84.62	$	82.13	$	99.48
Gas ($/Mcf)	$	4.71	$	4.24	$	3.74
BOE ($/BOE)	$	64.39	$	63.63	$	73.76
Expense per BOE (in dollars):
Lease operating expenses	$	22.06	$	32.10	$	25.09
Production and property taxes	$	7.35	$	7.44	$	8.90
Depletion, depreciation and amortization	$	20.94	$	18.02	$	24.47
General and administrative expense	$	84.15	$	50.73	$	84.52

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	31-Dec-13		31-Dec-12
Production Volume
Oil (Bbls)		25,424		36,626
Natural gas (Mcf)		80,972		92,678
BOE		38,919		52,072
Sales Price
Oil ($/Bbls)	$	92.01	$	79.28
Gas ($/Mcf)	$	4.26	$	3.94
BOE ($/BOE)	$	68.96	$	62.77
Expense per BOE (in dollars):
Lease operating expenses	$	23.67	$	28.87
Production and property taxes	$	7.98	$	6.73
Depletion, depreciation and amortization	$	22.66	$	20.01
General and administrative expense	$	84.33	$	54.14

The following table sets forth results of operations for the following periods:

	Three months ended
	31-Dec-13			31-Dec-12			2Q13 to 2Q12 change			30-Sep-13			2Q13 to 1Q13 Change
Oil sales	$	1,082,154		$	1,457,238		$	(375,084	)	$	1,256,990		$	(174,836	)
Gas sales		202,658			218,885			(16,227	)		141,946			60,712
Other liquids		627			-			627			-			627
Interest income		86,853			55,139			31,714			14,445			72,408
Gain on sale of oil and gas properties		-			-			-			2,524,411			(2,524,411	)
Other		85			111,469			(111,384	)		99			(14	)
Lease operating expense		(586,926	)		(1,041,761	)		454,835			(644,750	)		57,824
Depletion, depreciation and amortization		(417,723	)		(498,851	)		81,128			(464,082	)		46,359
Impairment		-			(244,560	)		244,560			(83,121	)		83,121
Exploration and evaluation expenditure		(51,669	)		(39,006	)		(12,663	)		(267,705	)		216,036
Accretion of asset retirement obligations		(17,117	)		(13,675	)		(3,442	)		(15,696	)		(1,421	)
General and administrative		(1,679,066	)		(1,336,332	)		(342,734	)		(1,603,046	)		(76,020	)
Income tax benefit		-			1,366,938			(1,366,938	)		-			-
Net income/(loss)	$	(1,380,124	)	$	35,484		$	(1,415,608	)	$	859,491		$	(2,239,615	)

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	Six months ended
	31-Dec-13			31-Dec-12			2Q13 to 2Q12 change
Oil sales	$	2,339,144		$	2,903,775		$	(564,631	)
Gas sales		344,604			364,907			(20,303	)
Other liquids		627			4,199			(3,572	)
Interest income		101,298			126,779			(25,481	)
Gain on sale of oil and gas properties		2,524,411			-			2,524,411
Other		184			111,481			(111,297	)
								-
Lease operating expense		(1,231,676	)		(1,853,750	)		622,074
Depletion, depreciation and amortization		(881,805	)		(1,089,618	)		207,813
Exploration and evaluation expenditure		(319,374	)		(400,950	)		81,576
Accretion of asset retirement obligations		(32,813	)		(27,109	)		(5,704	)
Impairment		(83,121	)		(244,589	)		161,468
General and administrative		(3,282,109	)		(2,819,114	)		(462,995	)
Income tax (provision)/ benefit		-			2,035,936			(2,035,936	)
Net income (loss)	$	(520,630	)	$	(888,053	)	$	367,423

Three Months Comparison of Quarter Ended December 31, 2013 to Quarter Ended December 31, 2012 and Six Month Comparison of the Period Ended December 31, 2013 to the Period Ended December 31, 2012.

Oil and gas revenues

Oil revenues decreased from $1.4 million for the three months ended December 31, 2012 to $1.1 million for the three months ended December 31, 2013, as a result of a decrease in our oil production which was partially offset by an increase in the realized price.  Oil production decreased from 17,744 barrels for the quarter ended December 31, 2012, to 12,788 barrels for the quarter ended December 31, 2013. Production decreased in the current quarter due to wells being shut in in our North Stockyard project for work overs or while other wells in the vicinity were drilled or fracced. The decrease in production from existing wells was partially offset by a new well coming online during the period ended December 31, 2013.  Our realized oil price increased from $82.13 for the quarter ended December 31, 2012, to $84.62 for the quarter ended December 31, 2013.

Oil revenues also decreased from $2.9 million for the six months ended December 31, 2012 to $2.3 million for the six months ended December 31, 2013 as a result of a decrease in our oil production, which was slightly offset by an increase in our realized oil price.  Oil production decreased from 36,626 barrels for the six months ended December 31, 2012 to 25,424 barrels for the six months ended December 31, 2013.  Our realized oil price increased from $79.28 for the six months ended December 31, 2012 to $92.01 for the six months ended December 31, 2013.

Gas revenues remained consistent at $0.2 million for the three months ended December 31, 2012 and 2013. Production decreased from 51,587 mcf for the quarter ended December 31, 2012 to 42,990 Mcf for the quarter ended December 31, 2013. This slight decrease in production was offset by a slight increase in the realized gas price per Mcf, from $4.24 for the quarter ended December 31, 2012 to $4.71 for the quarter ended December 31, 2013.

Gas revenues also remained consistent at $0.3 million for the six months ended December 31, 2012 and 2013. Production decreased from 92,678 Mcf for the six months ended December 31, 2012 to 80,972 Mcf for the six months ended December 31, 2013. This decrease in production was offset by an increase in the realized gas price per Mcf, from $3.94 for the six months ended December 31, 2012 to $4.26 for the six months ended December 31, 2013.

Sale of oil and gas properties

In August 2013, we divested half our equity position in the undeveloped acreage in the North Stockyard project to Slawson Exploration Company Inc. for $5.562 million in cash and other consideration while retaining our full interest in the currently producing wells in the North Stockyard field. As a consequence of the transaction the rig contract with Frontier was also terminated, without penalty. Slawson is now the operator of the project and responsible for the development of the remaining undeveloped acreage.

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Along with the undeveloped acreage, we also transferred a 25% working interest in the drilled but not yet completed, at the time of the sale, Sail and Anchor well, as well as a 25% working interest in the salt water disposal well drilled in the prior year in the North Stockyard project. A portion of the purchase price remains subject to the delivery of a useable well bore in Billabong, valued in the agreement at $0.9 million and other customary post-closing adjustments.

Exploration expense

Exploration expenditures increased slightly from $0.04 million for the quarter ended December 31, 2012, to $0.05 million for the quarter ended December 31, 2013. The expenditure in the prior period relates to expensing $0.26 million in additional expenditure in relation to our Australia II and Gretel II wells in our Roosevelt project in Montana. During the prior quarter we also wrote off $0.15 million in expenditure in relation to the Matson well in our South Prairie project in North Dakota. In the current quarter we recognized an additional $0.05 million in exploration expense in relation to the Matson well which was a dry hole.

Exploration expenditure decreased slightly from $0.4 million for the six months ended December 31, 2012 to $0.3 million for the six months ended December 31, 2013. During the six months ended December 31, 2012 the exploration expenditure relates to expenses incurred on our Australia II and Gretel II leases as well as other general exploration expenditure. During the six months ended December 31, 2013 the exploration expenditure relates to dry hole costs associated with the Matson well in our South Prairie project in North Dakota of $0.2 million plus other general exploration expenditure.

Lease operating expense

Lease operating expenses decreased from $1.0 million for the quarter ended December 31, 2012, to $0.6 million for the quarter ended December 31, 2013. This decrease is largely due to our Australia II and Gretel II wells being shut-in during the quarter in the Roosevelt Field. The Gretel II well in particular has produced a significant amount of water for which the disposal costs significantly add to lease operating costs. Costs per BOE decreased from $32.10 for the quarter ended December 31, 2012 to $22.06 for the quarter ended December 31, 2013.

Lease operating expenses decreased from $1.8 million for the six months ended December 31, 2012 to $1.2 million for the six months ended December 31, 2013. This decrease is due to a decrease in production as well as a decrease in the per barrel cost of lease operating expense. Costs per BOE decreased from $28.87 for the six months ended December 31, 2012 to $23.67 for the six months ended December 31, 2013.

Depletion, depreciation and amortization expense

Depletion, depreciation and amortization expense decreased slightly from $0.5 million for the quarter ended December 31, 2012 to $0.4 million for the quarter ended December 31, 2013. The per BOE cost increased from $18.02 for the three months ended December 31, 2012 to $20.94 for the three months ended December 31, 2013. This increase is due to new wells, which commenced production during the period being depleted for the first time, however production overall decreased, leading to the decrease in depletion expense.

Depletion, depreciation and amortization expense decreased from $1.09 million for the six months ended December 31, 2012 to $0.9 million for the six months ended December 31, 2013. Depreciation, depletion and amortization expense per BOE increased from $20.01 for the six months ended December 31, 2012 compared to $22.66 for the six months ended December 31, 2013, however production overall decreased, leading to the decrease in depletion expense.

General and administrative expense

General and administrative expense increased from $1.3 million for the quarter ended December 31, 2012 to $1.7 million for the three months ended December 31, 2013. This increase is largely due to an increase in corporate activity surrounding funding strategies and investor relations.

General and administrative expense increased from $2.8 million for the six months ended December 31, 2012 to $3.3 million for the six months ended December 31, 2013. This increase is largely due to an increase in corporate activity surrounding funding strategies and investor relations.

Income tax benefit

Income tax benefit was $nil for the three month period ended December 31, 2013, compared to a benefit of $1.4 million for the quarter ended December 31, 2012.  The income tax benefit recognized in the prior year is a result of a portion of prior year operating losses being carried back to obtain a refund of income taxes paid in prior years.

Income tax benefit was $nil for the six months ended December 31, 2013 compared to a benefit of $2.0 million for the six months ended December 31, 2012. The income tax benefit recognized in the prior year is a result of a portion of the prior year’s operating losses being carried back to obtain a refund of income taxes paid in prior years.

Cash Flows

The table below shows cash flows for the following periods: 

19

	Six months ended
	31-Dec-13			31-Dec-12
Cash provided by/(used in) operating activities	$	(1,600,564	)	$	(838,888	)
Cash (used in)/provided by investing activities		(11,862,746	)		(11,522,296	)
Cash provided by/(used in) financing activities		6,776,246			3,132,420

Cash used in operations increased from an outflow of $0.8 million for the six months ended December 31, 2012, to a net outflow of $1.6 million for the six months ended December 31, 2013. Cash receipts from customers decreased from $3.5 million for six months ended December 31, 2012 to $2.5 million for the six months ended December 31, 2013 due a decrease in production as a number of wells were shut in for the period for workovers or for the drilling and fraccing of offset wells.

Cash used in investing activities increased from $11.5 million for the six months ended December 31, 2012 to $11.9 million of cash used for the six months ended December 31, 2013. The cash outflow for the six months ended December 31, 2013, relates to drilling activities in our North Stockyard project in North Dakota. The cash outflow for the period ended December 31, 2012, relates to drilling and exploration activities conducted in our Hawk Springs and Roosevelt projects.

Cash provided by financing activities increased from a cash inflow of $3.1 million for the six months ended December 31, 2012, to a cash inflow of $6.8 million for the six months ended December 31, 2013. Cash inflow for the prior period was a result of the exercise of non-compensatory options. The increase in the current period is a result of shares issued during the period as described below. All options outstanding as at December 31, 2013 are currently out of the money.

During the six months ended December 31, 2013 we issued 318,452,166 ordinary shares for 2.5 cents (Australian cents)/2.3 cents (United States cents) for proceeds of $7.3 million before expenses. The ordinary shares were issued to investors in the US and Australia. The shares issued in the US were exchanged for American Depositary Shares.

Liquidity, Capital Resources and Capital Expenditures

Our primary use of capital has been acquiring, developing and exploring oil and natural gas properties and we anticipate this will be our primary use of capital during fiscal 2014 as well. 

Our current budget for exploration, exploitation and development capital expenditures in fiscal 2014 is $27.6 million, of which we incurred approximately $15.3 million during the first six months of the fiscal year. We were able to make these expenditures, which were required to participate in the drilling and completion of the first five wells in our North Stockyard infill development program, by using the proceeds from our recent registered direct offering and our sale of development acreage to Slawson. The remaining $12.3 million in planned capital expenditures, some of which depends upon obtaining additional financing, relates to the drilling and completion of three additional wells in our North Stockyard infill project.

In January 2014, we entered into a $25 million credit facility with Mutual of Omaha Bank, with an initial borrowing base of $8.0 million, of which $4.0 million has been drawn down. We expect the remaining $4.0 million in borrowing base will be drawn down prior to June 30, 2014 on an as needed basis. Additional increases in the borrowing base, up to the credit facility maximum of $25 million, may be made available to us in the future depending on the value of our reserves in the future. Borrowing base redeterminations are performed by Mutual of Omaha every six months at June and December. We also have the ability to request a borrowing base redetermination at another period, once a year.

The credit facility includes the following covenants, which will be tested on a quarterly basis:

· Current ratio greater than 1

· Debt to EBITDAX (annualized) ratio no greater than 3.5

· Interest coverage ratio minimum of 2.5 to 1.0

While we expect to be in compliance with these covenants at our current debt levels, in order to remain in compliance with our financial covenants and ratios under our credit facility in the future, we believe that we have several options available to us that we may pursue separately or in combination if necessary.

These funds will be used to fund drilling in our North Stockyard project in North Dakota. We expect to fund our remaining capital expenditures for fiscal 2014 with cash on hand and cash flow from operations, and we may obtain additional capital through equity finance raisings, further drawdowns of our credit facility (if possible) or another capital raising program or asset sales.

Uncertainties relating to our capital resources and requirements include the effects of results from our exploration and drilling program and changes in oil and natural gas prices, either of which could lead us to accelerate or decelerate exploration and drilling activities. The aggregate levels of capital expenditures for our fiscal year ending June 30, 2014, and the allocation of those expenditures, are dependent on a variety of factors, including the availability of capital resources to fund the expenditures and changes in our business assessments as to where our capital can be most profitably employed. Accordingly, the actual levels of capital resources and expenditures and the allocation of those expenditures may vary materially from our estimates.

20

We are continually monitoring the capital resources available to us to meet our future financial obligations, planned capital expenditure activities and liquidity.  Our future success in growing our proved reserves and production will be highly dependent on capital resources available to us and our success in finding or acquiring such additional productive reserves.

Our two main sources of liquidity during the fiscal year ending June 30, 2014 have been cash on hand, which was $5.9 million, excluding restricted cash, at December 31, 2013, cash flows from operations, our recent registered direct offering, the sale of development acreage to Slawson and the credit facility entered into subsequent to period end. We continue to explore various methods of obtaining additional capital during the remainder of the fiscal year, including additional sales of equity securities and further drawdowns of our credit facility during the remainder of the fiscal year.

During the past three fiscal years, our three main sources of liquidity were (i) approximately $73.2 million cash received from the sale of 24,166 acres in Goshen County, Wyoming to Chesapeake Energy Corporation, (ii) $6.3 million received from the sale of our interests in the Jonah and Lookout Wash fields and (iii) our tax refund of $5.6 million from the Internal Revenue Service, received in February 2013. Both sales occurred during the fiscal year ended June 30, 2011. During the recent years prior to the fiscal year ended June 30, 2011, our primary sources of liquidity were (i) equity raises and (ii) a loan facility with Macquarie Bank Limited, which we repaid in full on May 30, 2011.

Our cash on hand position as of December 31, 2013 decreased from the same period in the previous year largely due to payments for drilling and fraccing in our North Stockyard project in North Dakota.

If future drilling success rates or production are less than anticipated, the value of our position in affected areas will decline, our results of operations, financial condition and liquidity will be adversely impacted and we could incur material write-downs of unevaluated properties. See the risk factors in our Annual Report on Form 10-K for the fiscal year ended June 30, 2013 including “Drilling results in emerging plays, such as our Hawk Springs and Roosevelt Projects, are subject to heightened risks.” and “Inadequate liquidity could materially and adversely affect our business operations.” See also Part II, Item 1A of this report below.

 Looking Ahead

We plan to focus on two main objectives in the coming 12 months:

· The continued development of our North Stockyard project in Williams County, North Dakota.

· The continued appraisal and development of our Hawk Springs project, possibly through a farmout, including multiple conventional targets in the Permian and Pennsylvanian formations.

Our ability to meet these objectives will depend on our ability to raise additional capital to fund the planned development programs.

Item 3.   Quantitative and Qualitative Disclosures About Market Risk.

There were no material changes to the disclosure made in our Annual Report on Form 10-K for the year ended June 30, 2013 regarding this matter.

Item 4.    Controls and Procedures.

As of December 31, 2013, we have carried out an evaluation under the supervision of, and with the participation of, our management, including our Chief Executive Officer and Chief Financial Officer, of the effectiveness of the design and operation of our disclosure controls and procedures pursuant to Rule 13a-15 under the Securities Exchange Act of 1934, as amended (the “Exchange Act”).

Our Chief Executive Officer and Chief Financial Officer have concluded that, as of December 31, 2013, our disclosure controls and procedures were effective to ensure that the information required to be disclosed by us in the reports that we file or submit under the Exchange Act is recorded, processed, summarized and reported within the time periods specified in SEC rules and forms, and that information required to be disclosed by us in such reports is accumulated and communicated to our management, including our principal executive officer and principal financial officer, as appropriate, to allow timely decisions regarding required disclosure.  

There were no changes in our internal control over financial reporting that occurred during the three months ended December 31, 2013, that have materially affected, or are reasonably likely to materially affect, our internal control over financial reporting. We may make changes in our internal control procedures from time to time in the future.

21

Part II — Other Information

Item 1.    Legal Proceedings.

In the ordinary course of our business we are named from time to time as a defendant in various legal proceedings.  We maintain liability insurance and believe that our coverage is reasonable in view of the legal risks to which our business ordinarily is subject.

The State of North Dakota has made a claim against our wholly owned subsidiary, Samson Oil and Gas USA, Inc. relating to additional corporate income tax allegedly due for the years ended June 30, 2007 through June 30, 2011 in an amount of $597,852. On December 23, 2013, we filed a Statement of Grounds for Protest with the North Dakota Office of State Tax Commissioner responding to and protesting the allegations. At this time, we cannot predict the ultimate outcome of this disputed claim.

The Environmental Protection Agency has proposed a cash settlement of $60,000 in relation to a 400 barrel oil spill on the Pierce well site in February 2009. The spill was contained and the area rehabilitated to the satisfaction of the appropriate authorities in 2009. The costs associated with the spill and subsequent remediation were covered by our insurance. The settlement has not yet been paid and is included within the accrual balance on the Balance Sheet.

Item 1A.   Risk Factors.

In addition to the other information set forth in this Quarterly Report on Form 10-Q, you should carefully consider the factors discussed in Part I, Item 1A. “Risk Factors” in our Annual Report on Form 10-K for the fiscal year ended June 30, 2013.  The risks disclosed in our Annual Report on Form 10-K could materially affect our business, financial condition or future results.  The risks described in our Annual Report on Form 10-K are not the only risks facing us.  Additional risks and uncertainties not currently known to us or that we currently deem to be immaterial may also materially adversely affect our business, financial condition or operating results in the future.

Item 2.    Unregistered Sales of Equity Securities and Use of Proceeds.

Not applicable

Item 3.    Defaults Upon Senior Securities.

Not applicable.

Item 4.    Mine Safety Disclosures.

Not applicable. 

22

Item 5.    Other Information.

Not applicable.

Item 6.    Exhibits.

Exhibit No.	Title of Exhibit
31.1	Certification of the Principal Executive Officer pursuant to Section 302 of the Sarbanes-Oxley Act of 2002
31.2	Certification of the Principal Financial Officer pursuant to Section 302 of the Sarbanes-Oxley Act of 2002
32.1	Certifications of the Principal Executive Officer and Principal Financial Officer pursuant to Section 906 of the Sarbanes-Oxley Act of 2002
101	The following financial information from Samson Oil & Gas Limited’s Quarterly Report on Form 10-Q for the quarter ended December 31, 2013 is formatted in XBRL (eXtensible Business Reporting Language): (i)   Consolidated Balance Sheet, (ii)  Consolidated Statements of Operations, (iii)  Consolidated Statement of Changes in Stockholders’ Equity, (iv)  Consolidated Statements of Cash Flows, and (v) the Notes to Consolidated Financial Statements.

23

Signatures

Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized.

	SAMSON OIL & GAS LIMITED
Date:   February 10, 2014	By:	/s/Terence Barr
		Terence M. Barr
		Managing Director, President and Chief Executive Officer (Principal Executive Officer)
Date:  February 10, 2014	By:	/s/ Robyn Lamont
		Robyn Lamont
		Chief Financial Officer (Principal Financial Officer)

24

EX-31.1

EXHIBIT 31.1

CERTIFICATION OF CHIEF EXECUTIVE OFFICER

 PURSUANT TO SECTION 302 OF THE SARBANES-OXLEY ACT OF 2002

I, Terence M. Barr, certify that:

1. I have reviewed this Quarterly Report on Form 10-Q of Samson Oil & Gas Limited;

2. Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3. Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the company as of, and for, the periods presented in this report;

4. The company’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the company and have:

(a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the company, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c) Evaluated the effectiveness of the company’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d) Disclosed in this report any change in the company’s internal control over financial reporting that occurred during the period covered by the annual report that has materially affected, or is reasonably likely to materially affect, the company’s internal control over financial reporting; and

5. The company’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the company’s auditors and the audit committee of the company’s board of directors (or persons performing the equivalent functions):

(a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the company’s ability to record, process, summarize and report financial information; and

(b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the company’s internal control over financial reporting.

/s/ Terence Barr

Terence M. Barr

Managing Director, President and Chief Executive Officer

February 10, 2014

EX-31.2

EXHIBIT 31.2

CERTIFICATION OF CHIEF FINANCIAL OFFICER

 PURSUANT TO SECTION 302 OF THE SARBANES-OXLEY ACT OF 2002

I, Robyn Lamont, certify that:

1. I have reviewed this Quarterly Report on Form 10-Q of Samson Oil & Gas Limited;

2. Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3. Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the company as of, and for, the periods presented in this report;

4. The company’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the company and have:

(a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the company, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c) Evaluated the effectiveness of the company’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d) Disclosed in this report any change in the company’s internal control over financial reporting that occurred during the period covered by the annual report that has materially affected, or is reasonably likely to materially affect, the company’s internal control over financial reporting; and

5. The company’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the company’s auditors and the audit committee of the company’s board of directors (or persons performing the equivalent functions):

(a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the company’s ability to record, process, summarize and report financial information; and

(b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the company’s internal control over financial reporting.

/s/ Robyn Lamont

Robyn Lamont

Chief Financial Officer

February 10, 2014

EX-32.1

EXHIBIT 32.1

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350

AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002 (subsections (a) and (b) of Section 1350, Chapter 63 of Title 18, United States Code), the undersigned officers of Samson Oil & Gas Limited (the “Company”), do hereby certify, to such officer’s knowledge, that:

(1)   The Quarterly Report on Form 10-Q for the quarter and six months ended December 31, 2013 (the “Report”) fully complies with the requirements of section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(2)   The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company.

/s/ Terence Barr

Terence M. Barr

President, Chief Executive Officer and Managing Director

February 10, 2014

/s/ Robyn Lamont

Robyn Lamont

Chief Financial Officer

February 10, 2014

XML

Issue of Share Capital (Details)	3 Months Ended	6 Months Ended
	Sep. 30, 2013 USD ($)	Dec. 31, 2013 USD ($)	Dec. 31, 2012 USD ($)	Dec. 31, 2013 AUD
Issue of Share Capital [Abstract]
Shares issued upon exercise of options, shares		9,864
Net proceeds from option exercises		$ 347	$ 3,132,420
Shares issued to institutional investors		318,452,166
Price per share, shares issued		$ 0.023		0.025
Issue of share capital	$ 7,337,485

XML

Income Taxes (Schedule Of Effective Income tax Rate) (Details) (USD $)	3 Months Ended		6 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2013	Dec. 31, 2012
Income Taxes [Abstract]
Income tax benefit/(expense)		$ 1,366,938		$ 2,035,936
Effective tax rate	0.00%	102.67%	18.00%	70.00%

XML

Income Taxes

6 Months Ended

Dec. 31, 2013

Income Taxes [Abstract]

Income Taxes

2. Income Taxes

	Three months ended					Six months ended
	31-Dec-13		31-Dec-12		31-Dec-13		31-Dec-12
Income tax benefit/(expense)	$	-	$	1,366,938	$	-	$	2,035,936
Effective tax rate		0.00%		102.67%		18.00%		70.00%

Due to the Company's history of net operating losses and the uncertainty of future profitable operations, the Companyhas recorded a full valuation allowance against its deferred tax assets.

The Company has current year losses and available prior year cumulative net operating losses that may be carried forward to reduce taxable income in future years.  The Tax Reform Act of 1986 contains provisions that limit the utilization of net operation loss carryforwards if there has been a change in ownership as described in Internal Revenue Code Section 382.  The Company’s prior year losses are limited by IRC Section 382, however current year losses are not subject to these limitations.

In the tax year ended June 30, 2012, the Company had a taxable loss of $33 million which exceeded the amount of taxable income, after NOL, generated in the tax year ended June 30, 2011. As a result the loss from June 30, 2012 was carried back to the income year of June 30, 2011 generating a refund of tax paid in that year.  As such the balance of the June 30, 2013 losses will be carried forward along with a portion of the current year prior loss to offset future taxable income.

During the quarter ending March 31, 2013, the Company received a $5.6 million income tax refund from the Internal Revenue Service of the taxes paid in a prior period noted above.  $0.8 million remains as receivable in the Balance Sheet and is expected to be received within the current year.

ASC Topic 740 requires that a valuation allowance be provided if it is more likely than not that some portion or all deferred tax assets will not be realized.  The Company’s ability to realize the benefits of its deferred tax assets will depend on the generation of future taxable income through profitable operations. Due to the Company’s history of losses and the uncertainty of future profitable operations, the Company has recorded a full valuation allowance against its deferred tax assets.

XML

Sale of Oil and Gas Properties (Details) (USD $)	3 Months Ended	6 Months Ended
	Sep. 30, 2013	Dec. 31, 2013
Gain (Loss) on Sale of Oil and Gas Property [Abstract]
total value of slawson sale	$ 5,562,000
value applied to Billabong well	900,000
well cost reimbursement from slawson	2,920,000
Gain Loss On Sale Of Property		2,524,411
cash value of slawson sale net of billabong allocated	4,600,000
cash calls transferred to slawson	400,000
Proceeds From Sale Of Oil And Gas Property And Equipment		3,547,409
Restricted Cash and Cash Equivalents, Current		$ 722,680
percentage of interest sold	25.00%

XML

Equity Incentive Compensation (Summary Of Stock Option Activity) (Details) (USD $)	3 Months Ended		6 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2013	Dec. 31, 2012
Equity Incentive Compensation [Abstract]
Employee Service Share-based Compensation, Nonvested Awards, Total Compensation Cost Not yet Recognized	$ 0		$ 0
Share-based Compensation	$ 80,989	$ 72,011	$ 86,244	$ 152,061

XML

Fair Value Measurements (Schedule Of Fair Value, Assets And Liabilities Measured On Recurring And Nonrecurring Basis) (Details) (USD $)	Dec. 31, 2013	Jun. 30, 2013
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash and cash equivalents	$ 5,902,559	$ 13,170,627
Restricted Cash and Cash Equivalents	722,680
Carrying Value [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash and cash equivalents	5,902,559	13,170,627
Restricted Cash and Cash Equivalents	722,680
Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash and cash equivalents	5,902,559	13,170,627
Restricted Cash and Cash Equivalents	$ 722,680

XML

Commitments And Contingencies (Details) (USD $)	6 Months Ended
	Dec. 31, 2013
Commitments And Contingencies [Abstract]
CashsettlementEPAfine	$ 60,000

XML

Basis of Presentation

6 Months Ended

Dec. 31, 2013

Basis of Presentation [Abstract]

Basis of Presentation

1. Basis of Presentation

These Consolidated Financial Statements have been prepared in accordance with accounting principles generally accepted in the United States of America (GAAP) for interim financial reporting. All adjustments which are normal and recurring by nature, in the opinion of management, necessary for fair statement of Samson Oil & Gas Limited’s (the Company) Consolidated Financial Statements have been included herein. Interim results are not necessarily indicative of expected annual results because of the impact of fluctuations in prices received for oil and natural gas, as well as other factors. In the course of preparing the Consolidated Financial Statements, management makes various assumptions, judgments and estimates to determine the reported amounts of assets, liabilities, revenues and expenses, and in the disclosures of commitments and contingencies. Changes in these assumptions, judgments and estimates will occur as a result of the passage of time and the occurrence of future events, and, accordingly, actual results could differ from amounts previously established.

The Company’s Consolidated Financial Statements have been prepared on a basis consistent with the accounting principles and policies reflected in the Company’s audited financial statements as of and for the year ended June 30, 2013. The year-end Consolidated Balance Sheet presented herein was derived from audited Consolidated Financial Statements, but does not include all disclosures required by GAAP.

These Consolidated Financial Statements should be read in conjunction with our audited Consolidated Financial Statements included in our Annual Report on Form 10-K for the fiscal year ended June 30, 2013.

Accruals.Accrued liabilities at December  31, 2013 and June 30, 2013 consist primarily of estimates for goods and services received but not yet invoiced.

Prepayments. The components of prepayments for the periods ended December31, 2013 and June 30, 2013 include cash advanced to the operators of our drilling projects as a prepayment toward future expected drilling operations.  As at December  31, 2013 cash had been advanced to the operator of our North Stockyard infill development project for the drilling and/or completion of five wells.

Recent Accounting Standards

There are no new accounting pronouncements that have not been adopted by the Company as of December 31, 2013 that will have a material effect on the Company’s financial statements.

XML

Capitalized Exploration Expense (Details) (USD $)	6 Months Ended
	Dec. 31, 2013	Jun. 30, 2013
Capitalized Exploration Expense [Abstract]
Capiltalized exploration expense after write off	$ 2,700,000
Undeveloped capitalized acreage	12,369,412	12,369,412
undevelopedacreagecapitalisedHawkSprings	3,000,000
capitalisedexpenditureHawkSprings	1,500,000
costcapitalisedforBluffFederalWell	300,000
undevelopedacreageRoosevelt	7,800,000
CapitalisedExpenditureRoosevelt	300,000
UndevelopedAcreageCostsSouthPrairie	1,600,000
ExplorationExpenditureCapitalisedSouthPrairie	$ 900,000

XML

Consolidated Balance Sheets (USD $)	Dec. 31, 2013	Jun. 30, 2013
CURRENT ASSETS
Cash and cash equivalents	$ 5,902,559	$ 13,170,627
Restricted Cash	722,680
Accounts receivable, net of allowance for doubtful accounts of $nil and $nil respectively	2,716,219	3,090,666
Prepayments	5,103,646	411,113
Pipe inventory - held by third party		78,944
Income tax receivable	778,175	777,804
Total current assets	15,223,279	17,529,154
PROPERTY, PLANT AND EQUIPMENT, AT COST
Oil and gas properties, successful efforts method of accounting, less accumulated depreciation, depletion and impairment of $19,348,992 and $18,318,918 at December 31, 2013 and June 30, 2013, respectively.	25,521,914	19,992,018
Other property and equipment, net of accumulated depreciation and amortization of $406,232 and $351,037 at December 31, 2013 and June 30, 2013, respectivelyOther property and equipment, net of accumulated depreciation and amortization of $406,232 and $351,037 at December 31, 2013 and June 30, 2013, respectively	336,506	367,657
Net property, plant and equipment	25,858,420	20,359,675
OTHER ASSETS
Undeveloped capitalized acreage	12,369,412	12,369,412
Capitalized exploration expense	2,771,794	2,468,934
Other	94,019	79,490
TOTAL ASSETS	56,316,924	52,806,665
CURRENT LIABILITIES
Accounts payable	1,716,978	1,381,407
Accruals	2,599,603	5,406,982
Provision for annual leave	281,219	242,368
Total current liabilities	4,597,800	7,030,757
Asset retirement obligations	1,048,001	868,589
TOTAL LIABILITIES	5,645,801	7,899,346
STOCKHOLDERS' EQUITY - nil par value
2,547,627,193 (equivalent to 127,381,360 ADR's) and 2,229,165,163 (equivalent to 111,452,258 ADR's) ordinary shares issued and outstanding at December 31, 2013 and June 30, 2013, respectively	99,580,273	92,717,784
Other comprehensive income	1,400,195	1,978,250
Accumulated deficit	(50,309,345)	(49,788,715)
Total stockholders' equity	50,671,123	44,907,319
TOTAL LIABILITIES AND STOCKHOLDERS' EQUITY	$ 56,316,924	$ 52,806,665

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Consolidated Statements Of Changes In Stockholders' Equity (Parenthetical) (USD $)	3 Months Ended
	Sep. 30, 2013
Consolidated Statements Of Changes In Stockholders' Equity [Abstract]
Foreign currency translation, tax	$ 0

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Subsequent Event (Details) (USD $) In Millions, unless otherwise specified	6 Months Ended
	Dec. 31, 2013
Subsequent Events [Abstract]
Maximum credit facility	$ 25
Initial borrowing base	8
Initial draw down	$ 4

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Fair Value (Tables)

6 Months Ended

Dec. 31, 2013

Fair Value Measurements [Abstract]

Schedule Of Fair Value, Assets And Liabilities Measured On Recurring And Nonrecurring Basis

	Carrying value at December 31, 2013		Level 1		Level 2		Level 3		Fair Value at December 31, 2013
Assets
Cash and cash equivalents	$	5,902,559	$	5,902,559	$	-	$	-	$	5,902,559
Restricted cash		722,680		722,680		-		-		722,680
	Carrying value at June 30, 2013		Level 1		Level 2		Level 3		Fair Value at June 30, 2013
Assets
Cash and cash equivalents	$	13,170,627	$	13,170,627	$	-	$	-	$	13,170,627

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Income Taxes (Narrative) (Details) (USD $)	6 Months Ended
	Dec. 31, 2012	Dec. 31, 2013	Jun. 30, 2013
Income Taxes [Abstract]
Income tax refund received	$ (100)
Income tax receivable		$ 778,175	$ 777,804

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Consolidated Statements Of Cash Flows (USD $)	6 Months Ended
	Dec. 31, 2013	Dec. 31, 2012
Cash flows used in operating activities
Receipts from customers	$ 2,504,828	$ 3,487,463
Payments to suppliers & employees	(4,207,411)	(4,464,795)
Interest received	102,019	138,544
Income taxes paid		(100)
Net cash flows used in operating activities	(1,600,564)	(838,888)
Cash flows from investing activities
Proceeds from sale of oil and gas properties	3,547,409
Payments for plant & equipment	(25,041)	(10,392)
Payments for exploration and evaluation	(240,945)	(10,371,563)
Payments for oil and gas properties	(15,144,169)	(1,140,341)
Net cash flows used in investing activities	(11,862,746)	(11,522,296)
Cash flows from financing activities
Issuance of share capital	7,337,138
Proceeds from the exercise of options	347	3,132,420
Share issuance costs	(561,239)
Net cash flows provided by financing activities	6,776,246	3,132,420
Net decrease in cash and cash equivalents	(6,687,064)	(9,228,764)
Cash and cash equivalents at the beginning of the fiscal period	13,170,627	18,845,894
Effects of exchange rate changes on cash and cash equivalents	(581,004)	108,033
Cash and cash equivalents at end of fiscal period	$ 5,902,559	$ 9,725,163

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Consolidated Balance Sheets (Parenthetical) (USD $)	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2012	Jun. 30, 2012
Consolidated Balance Sheets [Abstract]
Other property and equipment, accumulated depreciation and amortization	$ 406,232		$ 351,037
Oil and Gas Property, Successful Effort Method, Accumulated Depreciation, Depletion and Amortization	$ 19,270,685		$ 18,318,918
Common stock, par value				$ 0		$ 0
Common stock, shares issued	2,547,627,193		2,229,165,163
Common stock, shares outstanding		2,547,627,193			2,547,627,193
Common stock, shares issued ADR	127,381,360		111,452,258
Common stock, shares outstanding ADR			111,452,258		127,381,360

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Issue of Share Capital

6 Months Ended

Dec. 31, 2013

Issue of Share Capital [Abstract]

Issue of Share Capital

10.  Issue of Share Capital

During the three months ended December 31, 2013 there were no issues of ordinary shares.

During the six months ended December 31, 2013, 9,864 Australian 3.8 cent options were exercised for net proceeds of $348. The options were issued in a public rights offering conducted in June 2013.

During the six months ended December 31, 2013 we issued 318,452,166 ordinary shares for 2.5 cents (Australian cents)/2.3 cents (United States cents) for proceeds of $7.3 million. The ordinary shares were issued to investors in the US and Australia.

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Document And Entity Information	3 Months Ended
	Dec. 31, 2013	Feb. 06, 2014
Document And Entity Information [Abstract]
Document Type	10-Q
Amendment Flag	false
Document Period End Date	Dec. 31, 2013
Document Fiscal Year Focus	2014
Document Fiscal Period Focus	Q2
Trading Symbol	SSN
Entity Registrant Name	Samson Oil & Gas LTD
Entity Central Index Key	0001404079
Current Fiscal Year End Date	--06-30
Entity Voluntary Filers	No
Entity Well-known Seasoned Issuer	No
Entity Current Reporting Status	Yes
Entity Filer Category	Accelerated Filer
Entity Common Stock, Shares Outstanding		2,547,627,193

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Cash Flow Statement

6 Months Ended

Dec. 31, 2013

Cash Flow Statement [Abstract]

Cash Flow Statement

11. Cash Flow Statement

Reconciliation of net income/(loss) after tax to the net cash flows from operations:

	Six months ended
	31-Dec-13		31-Dec-12
Net income/(loss) after tax	$	(520,630)	$	(888,053)
Depletion, depreciation and amortization		881,805		1,089,618
Stock based compensation		86,244		152,062
Accretion of asset retirement obligation		32,813		27,109
Impairment expense		83,121		244,589
Exploration and evaluation expenditure		319,374		400,950
Gain on sale of oil and gas properties		(2,524,411)		-
Changes in assets and liabilities:
(Increase)/decrease in receivables		(179,360)		24,074
(Increase)/decrease in income tax receivable/deferred tax asset		-		(2,036,036)
Increase/(decrease) in provision for annual leave		38,851		(37,643)
(Decrease)/Increase in payables		181,629		184,442
NET CASH FLOWS USED IN OPERATING ACTIVITIES	$	(1,600,564)	$	(838,888)

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Consolidated Statements Of Operations And Comprehensive Income (Loss) (USD $)	3 Months Ended		6 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2013	Dec. 31, 2012
REVENUES AND OTHER INCOME:
Interest income	$ 86,853	$ 55,139	$ 101,298	$ 126,779
Gain on sale of oil and gas properties			2,524,411
Other	85	111,469	184	111,481
TOTAL REVENUE AND OTHER INCOME	1,372,377	1,842,731	5,310,268	3,511,141
EXPENSES:
Lease operating expense	(586,926)	(1,041,761)	(1,231,676)	(1,853,750)
Depletion, depreciation and amortization	(417,723)	(498,851)	(881,805)	(1,089,618)
Impairment expense		(244,560)	(83,121)	(244,589)
Exploration and evaluation expenditure	(51,669)	(39,006)	(319,374)	(400,950)
Accretion of asset retirement obligations	(17,117)	(13,675)	(32,813)	(27,109)
General and administrative	(1,679,066)	(1,336,332)	(3,282,109)	(2,819,114)
TOTAL EXPENSES	(2,752,501)	(3,174,185)	(5,830,898)	(6,435,130)
Loss from operations	(1,380,124)	(1,331,454)	(520,630)	(2,923,989)
Income tax benefit		1,366,938		2,035,936
Net loss	(1,380,124)	35,484	(520,630)	(888,053)
OTHER COMPREHENSIVE GAIN (LOSS) [Abstract]
Foreign Currency Translation gain (loss)	(383,280)	(62,606)	(578,055)	89,070
Total comprehensiveincome/(loss) for the period	(1,763,404)	(27,122)	(1,098,685)	(798,983)
Net gain/(loss) per ordinary share from operations:
Basic - cents per share	$ (0.05)	$ 0.00	$ (0.02)	$ (0.05)
Diluted - cents per share	$ (0.05)	$ 0.00	$ (0.02)	$ (0.05)
Weighted average ordinary shares outstanding:
Basic	2,547,627,193	1,832,852,723	2,452,931,137	1,808,716,468
Diluted	2,547,627,193	1,955,132,196	2,452,931,137	1,808,716,468
Oil [Member]
REVENUES AND OTHER INCOME:
Sales	1,082,154	1,457,238	2,339,144	2,903,775
Gas [Member]
REVENUES AND OTHER INCOME:
Sales	202,658	218,885	344,604	364,907
Other Liquids [Member]
REVENUES AND OTHER INCOME:
Sales	$ 627	$ 0	$ 627	$ 4,199

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Equity Incentive Compensation

6 Months Ended

Dec. 31, 2013

Equity Incentive Compensation [Abstract]

Equity Incentive Compensation

5. Equity Incentive Compensation

Stock-based compensation is measured at the grant date based on the estimated fair value of the awards with the resulting amount recognized as compensation expense on a straight-line basis over the requisite service period (usually the vesting period).

Total compensation cost recognized in the Statements of Operations for the grants under the Company’s equity incentive compensation plans was $80,989 and  $72,011 during the three months ended December 31, 2013 and 2012 and$86,244 and$152,061 during the six months ended December 31, 2013 and 2012.

As of December 31, 2013, there was $niltotal unrecognized compensation cost related to outstanding stock options.

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Asset Retirement Obligations

6 Months Ended

Dec. 31, 2013

Asset Retirement Obligations [Abstract]

Asset Retirement Obligations

4. Asset Retirement Obligations

The Company’s asset retirement obligations primarily represent the estimated present value of the amounts expected to be incurred to plug, abandon and remediate producing and shut–in properties at the end of their productive lives in accordance with applicable state and federal laws. The Company determines the estimated fair value of its asset retirement obligations by calculating the present value of estimated cash flows related to plugging and abandonment liabilities. The significant inputs used to calculate such liabilities include estimates of costs to be incurred, the Company’s credit adjusted discount rates, inflation rates and estimated dates of abandonment. The asset retirement liability is accreted to its present value each period and the capitalized asset retirement cost is depleted using the units–of–production method.

During the three months ended September 30, 2013, we recorded an out-of-period adjustment to increase asset retirement obligations by $0.15 million, capitalized asset retirement costs by $0.085 million and expenses by $0.065 million. Based upon an evaluation of the relevant factors, we concluded that the related impact of this out-of-period adjustment was not material to our consolidated financial statements for any current or prior period.

The following table summarizes the activities for the Company’s asset retirement obligations for the six months ended December 31, 2013 and 2012:

	Six months ended
	31-Dec-13		31-Dec-12
Asset retirement obligations at beginning of period	$	868,589	$	808,572
Liabilities incurred or acquired		154,735		4,691
Liabilities settled		(8,136)		-
Disposition of properties		-		-
Accretion expense		32,813		27,109
Asset retirement obligations at end of period		1,048,001		840,372
Less: current asset retirement obligations (classified with accounts payable and accrued liabilities)		-		-
Long-term asset retirement obligations	$	1,048,001	$	840,372

Discount rates used to calculate the present value vary depending on the estimated timing of the obligation, but typically range between 4% and 9%.

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Cash Flow Statement Reconcilation (Tables)

6 Months Ended

Dec. 31, 2013

Cash Flow Statement [Abstract]

Schedule Of Cash Flow Statement Reconciliation

	Six months ended
	31-Dec-13		31-Dec-12
Net income/(loss) after tax	$	(520,630)	$	(888,053)
Depletion, depreciation and amortization		881,805		1,089,618
Stock based compensation		86,244		152,062
Accretion of asset retirement obligation		32,813		27,109
Impairment expense		83,121		244,589
Exploration and evaluation expenditure		319,374		400,950
Gain on sale of oil and gas properties		(2,524,411)		-
Changes in assets and liabilities:
(Increase)/decrease in receivables		(179,360)		24,074
(Increase)/decrease in income tax receivable/deferred tax asset		-		(2,036,036)
Increase/(decrease) in provision for annual leave		38,851		(37,643)
(Decrease)/Increase in payables		181,629		184,442
NET CASH FLOWS USED IN OPERATING ACTIVITIES	$	(1,600,564)	$	(838,888)

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Income Tax (Tables)

6 Months Ended

Dec. 31, 2013

Income Taxes [Abstract]

Schedule Of Effective Income tax Rate

	Three months ended					Six months ended
	31-Dec-13		31-Dec-12		31-Dec-13		31-Dec-12
Income tax benefit/(expense)	$	-	$	1,366,938	$	-	$	2,035,936
Effective tax rate		0.00%		102.67%		18.00%		70.00%

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Commitments And Contingencies

6 Months Ended

Dec. 31, 2013

Commitments And Contingencies [Abstract]

Commitments And Contingencies

8. Commitments and Contingencies

Environmental Matters

The Environmental Protection Agency has proposed a cash settlement of $60,000 in relation to a 400 barrel oil spill on the Pierce well site in February 2009.  The spill was contained and the area rehabilitated to the satisfaction of the appropriate authorities in 2009.  The costs associated with the spill and subsequent remediation were covered by our insurance. The settlement has not yet been paid and is included within the accrual balance on the Balance Sheet.

Other than the matter mentioned above, the Company has no accrued environmental liabilities for its sites, including sites in which governmental agencies have designated the Company as a potentially responsible party, because it is not probable that a loss will be incurred and the minimum cost and/or amount of loss cannot be reasonably estimated. However, due to uncertainties associated with environmental assessment and remediation activities, future expense to remediate the currently identified sites, and sites identified in the future, if any, could be incurred. Management believes, based upon current site assessments, that the ultimate resolution of any matters will not materially affect our results of operations or cashflows.

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Sale of Oil and Gas Properties

6 Months Ended

Dec. 31, 2013

Gain (Loss) on Sale of Oil and Gas Property [Abstract]

sale of oil and gas properties tex block

6. Sale of Oil and Gas Assets

In August 2013, we divested half our equity position in the undeveloped acreage in the North Stockyard project to Slawson Exploration Company Inc. (“Slawson”) for $5.562 million in cash and other consideration while retaining our full interest in the currently producing wells in the North Stockyard field.  $0.9 million of the cash portion of the purchase price is subject to the delivery of a useable well bore in Billabong. While work is continuing on this well bore, it had to be suspended to permit other drilling operations to proceed on the same pad.  The Billabong work is currently expected to recommence by the end of March 2014. The remaining $4.6 million in consideration was transferred into an escrow account on the sale date, less $0.4 million which was transferred to Slawson as it related to cash calls from other non-operator parties received by Samson prior to the sale. As at December 31, 2013,$3.5 million in sale funds have been released from the escrow account. The remaining $0.7 million is recorded as Restricted Cash on the Balance Sheet at December 2013. These funds are expected to be released to us prior the end of the quarter ending March 31, 2014.

As a consequence of the transaction the rig contract with Frontier was also terminated, with no penalty payment. Slawson are now the operator of the project going forward for the development of the undeveloped acreage. 

Along with the undeveloped acreage for which a gain on sale was recognized in the Income Statement of $2.52 million, we have alsotransferred a  25% working interest in the drilled but not completed, at the time of sale, Sail and Anchor well, as well as a 25% working interest in the salt water disposal well drilled in the prior year in the North Stockyard project for $2.92 million, recognized as a reimbursement in the capitalized costs for these assets on the December 31, 2013 Balance Sheet.

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Fair Value Measurements

6 Months Ended

Dec. 31, 2013

Fair Value Measurements [Abstract]

Fair Value Measurements

7. Fair Value Measurements

Fair value is defined as the price that would be received in the sale of 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 and the risks inherent in the inputs to the valuation technique. These inputs can be readily observable, market corroborated, or generally unobservable. The Company classifies fair value balances based on the observability of those inputs. The FASB has established 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 measurement) and the lowest priority to unobservable inputs (level 3 measurement).

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

 Level 1—Quoted prices are available in active markets for identical assets or liabilities as of the reporting date. Active markets are those in which transactions for the asset or liability occur in sufficient frequency and volume to provide pricing information on an ongoing basis.

 Level 2—Pricing inputs are other than quoted prices in active markets included in level 1, but are either directly or indirectly observable as of the reported date and for substantially the full term of the instrument. Inputs may include quoted prices for similar assets and liabilities. Level 2 includes those financial instruments that are valued using models or other valuation methodologies.

 Level 3—Pricing inputs include significant inputs that are generally less observable from objective sources. These inputs may be used with internally developed methodologies that result in management’s best estimate of fair value.

Financial assets and liabilities are classified in their entirety based on the lowest level of input that is significant to the fair value measurement. The Company’s assessment of the significance of a particular input to the fair value measurement requires judgment, and may affect the valuation of fair value assets and liabilities and their placement within the fair value hierarchy levels. The following table sets forth by level within the fair value hierarchy the Company’s financial assets and liabilities that were accounted for at fair value as of December 31, 2013 and June 30, 2013.

	Carrying value at December 31, 2013		Level 1		Level 2		Level 3		Fair Value at December 31, 2013
Assets
Cash and cash equivalents	$	5,902,559	$	5,902,559	$	-	$	-	$	5,902,559
Restricted cash		722,680		722,680		-		-		722,680
	Carrying value at June 30, 2013		Level 1		Level 2		Level 3		Fair Value at June 30, 2013
Assets
Cash and cash equivalents	$	13,170,627	$	13,170,627	$	-	$	-	$	13,170,627

The following methods and assumptions were used to estimate the fair value of the assets and liabilities in the table above:

Fair Value of Financial Instruments.   The Company’s financial instruments consist primarily of cash and cash equivalents, restricted cash, accounts receivable and payable and derivatives (discussed below). The carrying values of cash equivalents and accounts receivable and payable are representative of their fair values due to their short–term maturities.

Assets and Liabilities Measured at Fair Value on a Nonrecurring Basis. The Company also applies fair value accounting guidance to measure non–financial assets and liabilities such as business acquisitions, proved oil and gas properties, and asset retirement obligations. These assets and liabilities are subject to fair value adjustments only in certain circumstances and are not subject to recurring revaluations. These items are primarily valued using the present value of estimated future cash inflows and/or outflows. Given the unobservable nature of these inputs, they are deemed to be Level 3.

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Capitalized Exploration Expense

6 Months Ended

Dec. 31, 2013

Capitalized Exploration Expense [Abstract]

Capitalized Exploration Expense

9. Capitalized Exploration Expense

We use the successful efforts method of accounting for exploration and evaluation expenditure in respect of eacharea of interest. The application of this policy requires management to make certain estimates and assumptions as to future events and circumstances, in particular the assessment of whether economic quantities of reserves have been found.  Any such estimates and assumptions may change as new information becomes available.

Exploration and evaluation assets are assessed for impairment when facts and circumstances indicate that the carrying amount of an exploration and evaluation asset may exceed its recoverable amount.  When assessing for impairment consideration is given to but not limited to the following:

§ the period for which Samson has the right to explore;

§ planned and budgeted future exploration expenditure;

§ activities incurred during the year; and

§ activities planned for future periods.

If, after having capitalized expenditures under our policy, we conclude that we are unlikely to recover the expenditures through future exploitation, then the relevant capitalized amount will be written off to expense.

As of December 31, 2013 we had capitalized exploration expenditures of  $2.7  million and undeveloped capitalized acreage expenditures of $12.4 million.  This primarily relates to costs in relation to our Hawk Springs, Roosevelt and South Prairie projects.

Our Hawk Springs project, in Goshen County, Wyoming, includes $3.0 million in undeveloped capitalized acreage costs and $1.5 million in capitalized exploration expenditure. The capitalized exploration expenditure includes costs associated with the acquisition of our North Platte 3D seismic data.  During the six months ended December 31, 2013, we spent and capitalized $0.3 million on our Bluff Federal well in the Hawk Springs project.  This well is expected to be completed by June 2014.

Our Roosevelt project, in Roosevelt County, Montana, includes $7.8 million in undeveloped capitalized acreage costs and $0.3 million in capitalized exploration expenditure. The capitalized exploration expenditure consists of costs associated with well permitting, surface use agreements and other expenses associated with drilling preparation activities.  In December 2013, we entered into a seismic and drilling agreement with Momentus Energy Corp, a Canadian exploration and development company based in Calgary.  Momentus has committed to the acquisition of approximately 20 squares of 3-D seismic data at no cost to us. Following the acquisition of the seismic data, Momentus has the option to drill a horizontal Bakken well on our acreage at 100% cost to it.  Upon Momentus drilling this well, it will have earned the right to 50% of the test well and 50% of our acreage in the Roosevelt project.  This farm out is expected to be finalized by March 2014, with the acquisition of the 3-D seismic data to commence shortly after that.

Our South Prairie project in Ward and Renville counties, North Dakota, includes $1.6 million in undeveloped acreage costs and $0.9 million in capitalized exploration expenditure.  This expenditure relates to 3-D seismic acquisition costs. We are not the operator of this project. The joint venture is focusing on developing three structural closure prospects (Pubco, Deering, and Birch) along the Prairie Salt edge in the South Prairie 3-D project. The joint venture has approved that the Pubco Prospect will be drilled next on the eastern edge of the South Prairie 3-D seismic survey.  We anticipate this well will be drilled before the end of Q2 of calendar year 2014.

Exploration or divestment activities are continuing in all exploration areas. The outcome of these activities remains uncertain and may result in write offs in future periods if the related efforts prove unsuccessful.

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Cash Flow Statement (Details) (USD $)	6 Months Ended
	Dec. 31, 2013	Dec. 31, 2012
Cash Flow Statement [Abstract]
Net (loss) after tax	$ (520,630)	$ (888,053)
Depletion, depreciation and amortization	881,805	1,089,618
Stock based compensation	86,244	152,062
Accretion of asset retirment obligation	32,813	27,109
Impairment expense	83,121	244,589
Exploration and evaluation expenditure	319,374	400,950
Gain on sale of oil and gas properties	(2,524,411)
Increase in receivables	(179,360)	24,074
Increase in income tax receivable/deferred tax asset		(2,036,036)
Increase/(decrease) in provision for annual leave	38,851	(37,643)
Increase in payables	181,629	184,442
Net cash flows used in operating activities	$ (1,600,564)	$ (838,888)

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Asset Retirement Obligations (Tables)

6 Months Ended

Dec. 31, 2013

Asset Retirement Obligations [Abstract]

Summary Of Activities Of Asset Retirement Obligations

	Six months ended
	31-Dec-13		31-Dec-12
Asset retirement obligations at beginning of period	$	868,589	$	808,572
Liabilities incurred or acquired		154,735		4,691
Liabilities settled		(8,136)		-
Disposition of properties		-		-
Accretion expense		32,813		27,109
Asset retirement obligations at end of period		1,048,001		840,372
Less: current asset retirement obligations (classified with accounts payable and accrued liabilities)		-		-
Long-term asset retirement obligations	$	1,048,001	$	840,372

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Earnings Per Share (Details) (USD $)	3 Months Ended		6 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2013	Dec. 31, 2012
Earnings Per Share [Abstract]
Anti-dilutive	300,885,050	72,201,619	261,058,802	261,839,351
Net income	$ (1,380,124)	$ 35,484	$ (520,630)	$ (888,053)
Basic weighted average ordinary shares outstanding	2,547,627,193	1,832,852,723	2,452,931,137	1,808,716,468
Add: dilutive effect of stock options		95,791,227
Add: bonus element for rights issue		26,488,246
Diluted weighted average ordinary shares outstanding	2,547,627,193	1,955,132,196	2,452,931,137	1,808,716,468
Basic earnings per ordinary share - cents per share	$ (0.05)	$ 0.00	$ (0.02)	$ (0.05)
Diluted earnings per ordinary share - cents per share	$ (0.05)	$ 0.00	$ (0.02)	$ (0.05)

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Consolidated Statements Of Changes In Stockholders' Equity (USD $)	Ordinary Shares [Member]	Retained Earnings/(Accumulated Deficit) [Member]	Other Comprehensive Income (Loss) [Member]	Total
Balance at Jun. 30, 2013	$ 92,717,784	$ (49,788,715)	$ 1,978,250	$ 44,907,319
Net income				(520,630)
Net income (loss)		(520,630)
Foreign Currency Translation, net tax of $nil			(578,055)	(578,055)
Total comprehensiveincome/(loss) for the period		(520,630)	(578,055)	(1,098,685)
Stock based compensation	86,244
Issue of share capital	7,337,485
Share issue costs	(561,240)
Balance at December 31, 2013 at Dec. 31, 2013	$ 99,580,273	$ (50,309,345)	$ 1,400,195	$ 50,671,123

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Earnings Per Share

6 Months Ended

Dec. 31, 2013

Earnings Per Share [Abstract]

Earnings Per Share

3. Earnings Per Share

Basic earnings (loss) per share is calculated by dividing net earnings (loss) attributable to ordinary shares by the weighted average number of shares outstanding for the period. Under the treasury stock method, diluted earnings per share is calculated by dividing net earnings (loss) by the weighted average number of shares outstanding including all potentially dilutive ordinary shares (which in Samson’s case consists of unexercised stock options). In the event of a net loss, however no potential ordinary shares are included in the calculation of shares outstanding since the impact would be anti-dilutive.  

The following table details the weighted average dilutive and anti-dilutive securities outstanding, which consist of options, for the periods presented:

	Three months ended		Six months ended
	31-Dec-13	31-Dec-12	31-Dec-13	31-Dec-12
Dilutive	-	95,791,227	-	-
Anti–dilutive	300,885,050	72,201,619	261,058,802	261,839,351

The following tables set forth the calculation of basic and diluted earnings/(loss) per share: 

	Three months ended			Six months ended
	31-Dec-13		31-Dec-12	31-Dec-13		31-Dec-12
Net income (loss)	$	(1,380,124)	35,484	$	(520,630)	(888,053)
Basic weighted average ordinary shares outstanding		2,547,627,193	1,832,852,723		2,452,931,137	1,808,716,468
Add: dilutive effect of stock options		-	95,791,227		-	-
Add: bonus element for rights issue		-	26,488,246		-	-
Diluted weighted average ordinary shares outstanding		2,547,627,193	1,955,132,196		2,452,931,137	1,808,716,468
Basic earnings per ordinary share – cents per share		(0.05)	0.00		(0.02)	(0.05)
Diluted earnings per ordinary share – cents per share		(0.05)	0.00		(0.02)	(0.05)

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Asset Retirement Obligations (Details) (USD $)	3 Months Ended			6 Months Ended
	Dec. 31, 2013	Sep. 30, 2013	Dec. 31, 2012	Dec. 31, 2013	Dec. 31, 2012	Jun. 30, 2013
Asset Retirement Obligations [Line Items]
Asset retirement obligations at beginning of period		$ 868,589		$ 868,589	$ 808,572
Liabilities incurred or acquired				154,735	4,691
Liabilities settled				(8,136)
Accretion expense	17,117		13,675	32,813	27,109
Asset retirement obligations at end of period	1,048,001		840,372	1,048,001	840,372
Long-term asset retirement obligations	1,048,001		840,372	1,048,001	840,372	868,589
Out of period ARO adjustment to liabilities		150,000
ARO asset out of period adjustment		85,000
ARO expensed out of period adjustment		$ 65,000
Minimum [Member]
Asset Retirement Obligations [Line Items]
Asset Retirement Obligations, Discount Rate				4.00%	4.00%
Maximum [Member]
Asset Retirement Obligations [Line Items]
Asset Retirement Obligations, Discount Rate				9.00%	9.00%

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Earnings Per Share (Tables)

6 Months Ended

Dec. 31, 2013

Earnings Per Share [Abstract]

Schedule Of Weighted Average Dilutive And Anti-Dilutive Securities

	Three months ended		Six months ended
	31-Dec-13	31-Dec-12	31-Dec-13	31-Dec-12
Dilutive	-	95,791,227	-	-
Anti–dilutive	300,885,050	72,201,619	261,058,802	261,839,351

Schedule Of Calculation Of Basic And Diluted Earnings Per Share

	Three months ended			Six months ended
	31-Dec-13		31-Dec-12	31-Dec-13		31-Dec-12
Net income (loss)	$	(1,380,124)	35,484	$	(520,630)	(888,053)
Basic weighted average ordinary shares outstanding		2,547,627,193	1,832,852,723		2,452,931,137	1,808,716,468
Add: dilutive effect of stock options		-	95,791,227		-	-
Add: bonus element for rights issue		-	26,488,246		-	-
Diluted weighted average ordinary shares outstanding		2,547,627,193	1,955,132,196		2,452,931,137	1,808,716,468
Basic earnings per ordinary share – cents per share		(0.05)	0.00		(0.02)	(0.05)
Diluted earnings per ordinary share – cents per share		(0.05)	0.00		(0.02)	(0.05)