Legend Oil & Gas, Ltd. - FORM 10-Q

Legend Oil & Gas, Ltd. - FORM 10-Q - August 13, 2012

Attached files

Attached files

Legend Oil & Gas, Ltd. Reports

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EXCEL - IDEA: XBRL DOCUMENT - Legend Oil & Gas, Ltd.	Financial_Report.xls
EX-31.2 - EX-31.2 - Legend Oil & Gas, Ltd.	d343828dex312.htm
EX-31.1 - EX-31.1 - Legend Oil & Gas, Ltd.	d343828dex311.htm
EX-32.1 - EX-32.1 - Legend Oil & Gas, Ltd.	d343828dex321.htm

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 June 30, 2012

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

For the transition period from to

Commission File No.: 000-49752

Legend Oil and Gas, Ltd.

(Exact name of registrant as specified in its charter)

Colorado

84-1570556

(State or other jurisdiction of

incorporation or organization)

(IRS Employer

Identification No.)

1218 3^rd Avenue, Suite 505

Seattle, Washington 98101

(Address of principal executive offices)

(206) 274-5165

(Registrant’s telephone number, including area code)

1420 5th Avenue, Suite 2200, Seattle, Washington 98101

(Former name, former address and former fiscal year, if changed since last report.)

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. Yes x 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 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

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

As of August 2, 2012, the registrant had 75,362,031 shares of its common stock, par value $0.001 per share, issued and outstanding.

LEGEND OIL AND GAS, LTD.

FORM 10-Q

For the Quarterly Period ended June 30, 2012

Table of Contents


		Page
EXPLANATORY NOTE			2
CAUTIONARY NOTICE REGARDING FORWARD LOOKING STATEMENTS			2
PART I. FINANCIAL INFORMATION
Item 1.	Financial Statements (Unaudited)
	Consolidated Balance Sheets as of June 30, 2012 and December 31, 2011		3
	Consolidated Statements of Operations for the three and six months ended June 30, 2012 and 2011		4
	Consolidated Statements of Comprehensive Loss for the three and six months ended June 30, 2012 and 2011		5
	Consolidated Statements of Stockholders’ Equity for the for the six months ended June 30, 2012 and year ended December 31, 2011		6
	Consolidated Statements of Cash Flows for the for the six months ended June 30, 2012 and 2011		7
	Notes to Consolidated Financial Statements		8
Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations		18
Item 3.	Defaults Upon Senior Securities		25
Item 4.	Controls and Procedures		25

PART II. OTHER INFORMATION
Item 5	Other Information		25
Item 6.	Exhibits		26

SIGNATURES			27

EXHIBITS			28

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EXPLANATORY NOTE

Unless otherwise indicated or the context otherwise requires, all references in this Quarterly Report on Form 10-Q (“Report”) to “we,” “us,” “our,” “Legend” and the “Company” are to Legend Oil and Gas, Ltd., a Colorado corporation, and references in this Report to “Legend Canada” are to Legend Energy Canada, Ltd., a wholly-owned subsidiary of the Company. All references to “Sovereign” are to International Sovereign Energy Corp., an Alberta, Canada corporation. Unless otherwise indicated, references herein to “$” or “dollars” are to United States dollars. All references in this Current Report to “CA$” are to Canadian dollars. All financial information with respect to the Company has been presented in United States dollars in accordance with U.S generally accepted accounting principles.

CAUTIONARY NOTICE REGARDING FORWARD-LOOKING STATEMENTS

We desire to take advantage of the “safe harbor” provisions of the Private Securities Litigation Reform Act of 1995. This Report contains a number of forward-looking statements that reflect management’s current views and expectations with respect to our business, strategies, future results and events, and financial performance. All statements made in this Report other than statements of historical fact, including statements that address operating performance, the economy, events or developments that management expects or anticipates will or may occur in the future, including statements related to revenues, profitability, adequacy of funds from operations, and cash flows and financing are forward-looking statements. In particular, the words such as “believe,” “expect,” “intend,” “anticipate,” “estimate,” “may,” “will,” “can,” “plan,” “predict,” “could,” “future,” variations of such words, and similar expressions identify forward-looking statements, but are not the exclusive means of identifying such statements and their absence does not mean that the statement is not forward-looking.

Readers should not place undue reliance on these forward-looking statements, which are based on management’s current expectations and projections about future events, are not guarantees of future performance, are subject to risks, uncertainties and assumptions and apply only as of the date of this Report. Our actual results, performance or achievements could differ materially from historical results as well as the results expressed in, anticipated or implied by these forward-looking statements.

In particular, our business, including our financial condition and results of operations and our ability to continue as a going concern may be impacted by a number of factors, including, but not limited to, the following:

•

Our ability to pay off our demand loan facility with National Bank of Canada when due;

•

Our ability to draw down on our equity line of credit with Lincoln Park Capital Fund, LLC, in amounts and times when needed;

•

Our ability to fund our 2012 drilling and development plan;

•

Our ability to obtain buyers on terms favorable to us, in the event that we were to seek to sell certain of our oil and gas interests;

•

The exercise of put rights held by holders of our preferred stock and by Sovereign;

•

Our ability to retain the services of our President, Chief Financial Officer and other key employees, the loss of which could materially impair our business plan;

•

Changes in estimates of our crude oil and natural gas reserves and depletion rates;

•

Our ability to control or reduce operating expenses and manage unforeseen costs;

•

Our reliance on third-party contractors in performing the majority of our operations, which could make management of our drilling and production efforts inefficient or unprofitable;

•

Our ability to maintain our existing property leases and acquire rights on properties that we desire;

•

Changes in commodity prices for crude oil and natural gas;

•

Environmental risks from operations of our wells;

•

Our ability to compete successfully against larger, well-funded, established oil and gas companies;

•

Our ability to comply with the many regulations to which our business is subject; and

•

Dilutive and other adverse effects on our existing shareholders and our stock price arising from future securities issuances.

For a more detailed discussion of some of the factors that may affect our business, results and prospects, see our Annual Report on Form 10-K for the year ended December 31, 2011 filed with the Securities and Exchange Commission on March 30, 2012, as well as various disclosures made by us in our other reports filed with the Securities and Exchange Commission. Except as required by law, we undertake no obligation to publicly update or revise any forward-looking statements, whether as a result of new information, future events or otherwise.

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PART I – FINANCIAL INFORMATION

ITEM 1 CONSOLIDATED FINANCIAL STATEMENTS

Legend Oil and Gas Ltd.

CONSOLIDATED BALANCE SHEETS


	June 30, 2012			December 31, 2011
	(unaudited)			(audited)
ASSETS
Current Assets
Cash and cash equivalents	$	71,689		$	52,726
Accounts receivable		329,417			388,792
Stock subscription receivable		100,000			—
Prepaid expenses		155,792			90,109

Total current assets		656,898			531,627
Deposits and other assets		142,620			3,740
Oil and gas property, plant and equipment
Proven property - net		7,802,286			8,499,199
Unproven property		8,363,852			8,335,380

Total oil and gas properties, net		16,166,138			16,834,579

Total assets	$	16,965,656		$	17,369,946

LIABILITIES AND STOCKHOLDERS’ EQUITY (DEFICIT)
Current Liabilities
Accounts payable	$	909,790		$	312,553
Contingent consideration		—			1,404,059
Note payable to bank		5,323,590			5,094,042

Total current liabilities		6,233,380			6,810,654
Asset retirement obligations		1,625,360			1,601,423

Total liabilities		7,858,740			8,412,077
Contingently redeemable convertible preferred stock (100,000,000 shares authorized; $0.001 par value; 1,700,000 and 2,300,000 shares issued and outstanding , respectively; redemption $2.00 per share)		366,953			496,467
Contingently redeemable common stock		49,805,527			7,105,032

		50,172,480			7,601,499
Stockholders’ Equity (Deficit)
Common stock - 400,000,000 shares authorized; $0.001 par value; 74,345,764 and 50,582,516 shares issued and outstanding, respectively		74,346			50,583
Additional paid-in capital		(28,185,866	)		7,691,161
Accumulated other comprehensive loss		(33,795	)		(42,438	)
Accumulated deficit		(12,920,249	)		(6,342,936	)

Total stockholders’ equity (deficit)		(41,065,564	)		1,356,370

Total liabilities and stockholders’ equity (deficit)	$	16,965,656		$	17,369,946

The accompanying notes are an integral part of these consolidated financial statements.

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Legend Oil and Gas Ltd.

CONSOLIDATED STATEMENTS OF OPERATIONS

(unaudited)


	For the Three Months Ended						For the Six Months Ended
	June 30, 2012			June 30, 2011			June 30, 2012			June 30, 2011
Oil and gas revenue	$	588,016		$	49,791		$	1,286,264		$	95,611

Costs and Expenses
General and administrative		911,875			103,766			1,923,481			225,764
Production expenses		422,559			48,834			851,077			82,485
Depletion, depreciation, and amortization		381,799			19,794			802,584			19,794
Accretion on asset retirement obligation		12,914			—			25,940			—

Total costs and expenses		1,729,147			172,394			3,603,082			328,043

Operating Loss		(1,141,131	)		(122,603	)		(2,316,818	)		(232,432	)

Other Income and Expense
Interest expense		(57,381	)		—			(114,083	)		—
Interest income		—			35			—			121
Change in value of contingent consideration		(4,189,836	)		—			(4,146,412	)		—

Total other income and expense		(4,247,217	)		35			(4,260,495	)		121

Net loss	$	(5,388,348	)	$	(122,568	)	$	(6,577,313	)	$	(232,311	)

Basic and diluted weighted average shares outstanding		61,791,272			50,435,385			56,216,894			56,457,569

Basic and diluted net loss per share	$	(0.09	)	$	(0.00	)	$	(0.12	)	$	(0.00	)

The accompanying notes are an integral part of these consolidated financial statements.

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Legend Oil and Gas Ltd.

CONSOLIDATED STATEMENTS OF COMPREHENSIVE LOSS

(unaudited)


	For the Three Months Ended						For the Six Months Ended
	June 30, 2012			June 30, 2011			June 30, 2012			June 30, 2011
Net loss	$	(5,388,348	)	$	(122,568	)	$	(6,577,313	)	$	(232,311	)
Other comprehensive loss
Foreign currency translation adjustment		(141,878	)		—			8,643			—

Comprehensive loss	$	(5,530,226	)	$	(122,568	)	$	(6,568,670	)	$	(232,311	)

The accompanying notes are an integral part of these consolidated financial statements.

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Legend Oil and Gas Ltd.

STATEMENTS OF CONSOLIDATED STOCKHOLDERS’ EQUITY

(unaudited)


	Common Stock						Additional Paid-in Capital			Accumulated other comprehensive gain/(loss)			Accumulated Deficit			Total
Balance at December 31, 2010		62,360,000		$	62,360		$	980,472		$	—		$	(293,601	)	$	749,231
Issuance of common stock and warrants February 2011		300,000			300			149,700			—			—			150,000
Cancellation of stock by shareholders April 2011		(15,890,000	)		(15,890	)		15,890			—			—			—
Issuance of common stock and warrants April 2011		250,000			250			249,750			—			—			250,000
Issuance of convertible preferred stock and warrants August 2011		—			—			4,103,533			—			—			4,103,533
Common stock issued for services		10,000			10			19,990			—			—			20,000
Issuance of common stock October 2011 as part of acquisition		3,552,516			3,553			706,952			—			—			710,505
Stock based compensation		—			—			1,464,874			—			—			1,464,874
Foreign currency translation		—			—			—			(42,438	)		—			(42,438	)
Net loss		—			—			—			—			(6,049,335	)		(6,049,335	)

Balance at December 31, 2011		50,582,516			50,583			7,691,161			(42,438	)		(6,342,936	)		1,356,370
Common stock issued for services		60,000			60			59,940			—			—			60,000
Conversion of convertible preferred stock to common stock		600,000			600			128,913			—			—			129,513
Issuance of common stock May 2012, net		915,900			916			247,394			—			—			248,310
Issuance of common stock to settle contingent consideration obligation		21,350,247			21,350			(37,170,780	)		—			—			(37,149,430	)
Issuance of common stock June 2012, net		837,101			837			149,163			—			—			150,000
Stock based compensation		—			—			708,343			—			—			708,343
Foreign currency translation		—			—			—			8,643			—			8,643
Net loss		—			—			—			—			(6,577,313	)		(6,577,313	)

Balance at June 30, 2012		74,345,764		$	74,346		$	(28,185,866	)	$	(33,795	)	$	(12,920,249	)	$	(41,065,564	)

The accompanying notes are an integral part of these consolidated financial statements.

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Legend Oil and Gas Ltd.

CONSOLIDATED STATEMENTS OF CASH FLOWS

(unaudited)


	For the six months ended
	June 30, 2012			June 30, 2011
CASH FLOWS FROM OPERATING ACTIVITIES:
Net loss	$	(6,577,313	)	$	(232,311	)

Adjustments to reconcile net loss to cash flows from operating activities:
Stock-based compensation		708,343			—
Accretion on asset retirement obligation		25,940			—
Issuance of common stock for services		60,000			—
Change in value of contingent consideration liability		4,146,412			—
Depletion, depreciation, amortization and impairment		802,584			19,794
Changes in operating assets and liabilities:
Accounts and subscriptions receivable		59,963			831
Prepaid expenses and other assets		2,934			14,701
Accounts payable		603,602			21,620

Net cash flows from operating activities		(167,535	)		(175,365	)

CASH FLOWS FROM INVESTING ACTIVITIES:
Purchase of oil and gas properties		(142,438	)		(171,774	)

Net cash flows from investing activities		(142,438	)		(171,774	)

CASH FLOWS FROM FINANCING ACTIVITIES:

Proceeds from issuance of common stock and warrants		90,000			400,000
Proceeds from note payable to bank		229,548			—

Net cash flows from financing activities		319,548			400,000

Change in cash and cash equivalents before effect of exchange rate changes		9,575			52,861
Effect of exchange rate changes		9,388			—

Net change in cash and cash equivalents		18,963			52,861
Cash and cash equivalents, beginning of period		52,726			100,894

Cash and cash equivalents, end of period	$	71,689		$	153,755

SUPPLEMENTAL DISCLOSURES OF CASH FLOW INFORMATION:
Cash paid during the year for:
Interest	$	109,333		$	—

NON-CASH INVESTING AND FINANCING ACTIVITIES
Stock subscription receivable	$	100,000		$	—
Common stock issued under purchase agreement	$	208,311		$	—
Common stock issued for contingent consideration	$	5,550,471		$	—
Common stock classified as contingently redeemable	($	42,700,494	)	$	—
Conversion of convertible preferred stock to common stock	$	129,513		$	—

The accompanying notes are an integral part of these consolidated financial statements.

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Legend Oil and Gas Ltd.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

NOTE 1 - ORGANIZATION AND DESCRIPTION OF OPERATIONS

Description of Business

We are an oil and gas exploration, development and production company. Our oil and gas property interests are located in Western Canada (in Berwyn, Medicine River, Boundary Lake, Red Earth, Swan Hills and Wildmere in Alberta, and Clarke Lake and Inga in British Columbia) and in the United States (in the Piqua region of the State of Kansas and in the Bakken and Three Forks formations in Divide County, North Dakota). Subsequent to the quarter ended June 30, 2012, we entered into an agreement for the sale of our oil and gas property interests located in the Red Earth area of Alberta, Canada. See “Note 7 – Subsequent Events” below.

The Company was incorporated under the laws of the State of Colorado on November 27, 2000 under the name “SIN Holdings, Inc.” From inception until June 2010, we pursued our original business plan of developing a web portal listing senior resources across the United States through our former wholly-owned subsidiary Senior-Inet, Inc. On July 29, 2010, Senior-Inet, Inc. was dissolved and we changed our business to the acquisition, exploration, development and production of oil and gas reserves. To align our name with our new business, on November 29, 2010, we changed our name to Legend Oil and Gas, Ltd.

On July 28, 2011, we formed a wholly owned subsidiary named Legend Energy Canada, Ltd. (“Legend Canada”), which is a corporation registered under the laws of Alberta, Canada. Legend Canada was formed to acquire, own and manage certain oil and gas properties and assets located in Canada. Legend Canada completed the acquisition of significant oil and gas reserves located in Canada on October 20, 2011.

NOTE 2 - SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

Principles of Consolidation

The consolidated financial statements include the accounts of the Company and our wholly-owned subsidiary, Legend Canada. Intercompany transactions and balances have been eliminated in consolidation. We account for our undivided interest in oil and gas properties using the proportionate consolidation method, whereby our share of assets, liabilities, revenues and expenses are included in the financial statements.

Interim Reporting

The unaudited financial information furnished herein reflects all adjustments, consisting solely of normal recurring items, which in the opinion of management are necessary to fairly state the financial position of Legend Oil & Gas Ltd. and the results of its operations for the periods presented. This report on Form 10-Q should be read in conjunction with the Company’s consolidated financial statements and notes thereto included in the Company’s Form 10-K for the fiscal year ended December 31, 2011. The Company assumes that the users of the interim financial information herein have read or have access to the audited financial statements for the preceding fiscal year and that the adequacy of additional disclosure needed for a fair presentation may be determined in that context. Accordingly, footnote disclosure, which would substantially duplicate the disclosure contained in the Company’s Form 10-K for the fiscal year ended December 31, 2011 has been omitted. The results of operations for the interim periods presented are not necessarily indicative of results for the entire year ending December 31, 2012.

Use of Estimates

The preparation of financial statements in conformity with U.S. generally accepted accounting principles (“U.S. GAAP”) requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and the reported amounts of revenues and expenses during the reporting period. Management’s judgments and estimates in these areas are to be based on information available from both internal and external sources, including engineers, geologists, consultants and historical experience in similar matters. The more significant

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reporting areas impacted by management’s judgments and estimates are accruals related to oil and gas sales and expenses, estimates of future oil and gas reserves, estimates used in the impairment of oil and gas properties, and the estimated future timing and cost of asset retirement obligations.

Actual results could differ from the estimates as additional information becomes known. The carrying values of oil and gas properties are particularly susceptible to change in the near term. Changes in the future estimated oil and gas reserves or the estimated future cash flows attributable to the reserves that are utilized for impairment analysis could have a significant impact on the future results of operations.

Cash and Cash Equivalents

We consider all highly liquid short-term investments with original maturities of three months or less to be cash equivalents.

Accounts Receivable

Accounts receivable are due under normal trade terms and are presented on the consolidated balance sheets net of allowances for doubtful accounts. We establish provisions for losses on accounts receivable for estimated uncollectible accounts and regularly review collectability and establish or adjust the allowance as necessary using the specific identification method. Account balances that are deemed uncollectible are charged off against the allowance. No allowance for doubtful accounts was necessary as of June 30, 2012 and December 31, 2011.

Comprehensive Income

For operations outside of the U.S. that prepare financial statements in currencies other than U.S. dollars, we translate the financial statements into U.S. dollars. Results of operations and cash flows are translated at average exchange rates during the period, and assets and liabilities are translated at end of period exchange rates, except for equity transactions and advances not expected to be repaid in the foreseeable future, which are translated at historical costs. The effects of exchange rate fluctuations on translating foreign currency assets and liabilities into U.S. dollars are accumulated as a separate component in other comprehensive income (loss). Accumulated other comprehensive income (loss) consists entirely of foreign currency translation adjustments at June 30, 2012 and December 31, 2011.

Liquidity

We have incurred net operating losses and operating cash flow deficits over the last two years, continuing through the second quarter of 2012. We are in the early stages of acquisition and development of oil and gas leaseholds, and we have been funded primarily by a combination of equity issuances and bank debt, and to a lesser extent by operating cash flows, to execute on our business plan of acquiring working interests in oil and gas properties and for working capital for production. At June 30, 2012, we had cash and cash equivalents totalling approximately $72,000.

In October 2011, we established a revolving demand loan with National Bank of Canada through our wholly-owned subsidiary, Legend Canada. The credit facility had a maximum borrowing base of CA$6.0 million. On March 25, 2012, we received notification from the Bank of its decision to reduce and restructure our credit facility, following their interim review in the first quarter of 2012. The Bank advised us that it decided to reduce the maximum borrowing base under the credit facility due to decreases in the market prices of natural gas and the resulting decrease in the value of our reserves securing the credit facility. On March 27, 2012, we entered into an Amending Offering Letter with the Bank to amend the credit facility on the following terms: (a) the revolving demand loan was reduced from CA$6.0 million to CA$4.0 million, which is payable in full at any time upon demand by the Bank; (b) the Bank provided a new CA$1.5 million bridge demand loan, which was payable in full at any time upon demand by the Bank, and in any event no later than May 31, 2012; and (c) we were required to provide an unlimited guarantee of the credit facility for Legend Canada. Outstanding principal under the bridge demand loan bears interest at the Bank’s prime rate of interest plus 2.0% (the Bank’s current prime rate is 3.0%). In connection with the Amending Offering Letter, on March 27, 2012, Legend Canada entered into a CA$1.5 million variable rate demand note to the Bank, and we paid CA$15,000 to the Bank as a non-refundable bridge fee. In May 2012, we entered into an unlimited guarantee of the credit facility in favor of the Bank, and we also entered into a blanket security

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agreement, granting to the Bank a security interest in all of our personal property assets to secure the guarantee. On June 5, 2012, we entered an Amending agreement that extended the repayment of the bridge demand loan to December 1, 2012, with CA$250,000 monthly payments being made beginning July 15, 2012 and last payment on December 1, 2012. On June 13, 2012, we received notification that as a result of our May 31, 2012 bank review, our revolving credit facility would remain at CA$4.0 million and that our next scheduled reviewed would be December 1, 2012.

As of the date of this Report, we have an outstanding balance under the revolving demand loan with the Bank in the amount of approximately $3,968,000 (CA$3,975,000) and approximately $1,248,000 (CA$1,250,000) under the bridge demand loan. The Bank may demand repayment of all amounts owed by Legend Canada to it at any time. There is no assurance that any portion of this credit facility will be available to Legend Canada in the future.

The Amending Offering Letter with the Bank originally required that we complete an equity financing of at least CA$1.5 million on or before May 31, 2012, the proceeds of which were required to be used to pay off the bridge demand loan. In conjunction with June 5, 2012, Amending agreement, the Company agreed to enter into an equity financing, the proceeds of which would be used as required to make the periodic CA$250,000 payments. Subsequently on May 22, 2012, the Company entered into an agreement with Lincoln Park Capital (“Lincoln Park”) to sell up to $10.2 million in common stock during a three year term. This agreement permits the Company to sell stock to LPC at increments of 250,000 shares, with timing based on the Company’s discretion. There is a $0.10 per share floor price that would prohibit the Company from any sales below that price. At the date of this Report, the Company has sold and issued 2,769,268 common shares to Lincoln Park, and received $344,000 in funding.

Subsequent to June 30, 2012, and discussed in Note 7, the Company agreed on July 26, 2012 to sell its oil and gas interests in the Red Earth, Alberta property for CA$750,000 in gross proceeds. This transaction is expected to close on or about August 7, 2012. The revolving bank line borrowing base will be reduced by CA$150,000 as a result of this sale. It is management’s intention to use the net proceeds, after the costs of the sale, for the next scheduled monthly bridge loan payment and to retire current liabilities in working capital. From time to time, we may seek to sell certain of our other oil and gas properties.

We believe that the combination of revenue from our on-going operations, proceeds from the Red Earth sale and potential future asset sales, and our equity financing arrangement with Lincoln Park provide us the ability to make our scheduled monthly bridge loan payments. However, in the event we are unable to meet a bridge loan scheduled payment or the repayment of the revolving demand loan at any time upon demand by the Bank, we will be in default of our obligations to the Bank. The Bank has a first priority security interest in all of our assets and can exercise its rights and remedies against us as a secured creditor. Any such default by us or action by the Bank will have a material adverse effect on us and our business. If we are unable to negotiate favorably with the Bank, or if we are unable to secure additional financing, whether from equity, debt, or alternative funding sources, this could have a material adverse effect on us and we may be required to sell some or all of our properties, sell or merge our business, or file a petition for bankruptcy.

In addition, Sovereign and the holders of our convertible preferred stock have “put” rights to require us to repurchase their shares at a price of $2.00 per share. These put rights became exercisable on April 1, 2012. As of March 30, 2012, we received signed waivers from the holders of our convertible preferred stock of their put rights; however, these waivers are contingent on Sovereign also agreeing to waive its rights. In addition, as of March 31, 2012, Sovereign executed a stand-still agreement agreeing not to exercise its put rights prior to June 15, 2012, and Sovereign has subsequently verbally agreed to extend the stand-still agreement for an unspecified period of time. We currently do not have sufficient cash assets available to repurchase the shares of convertible preferred stock or the shares of common stock issued to Sovereign in the event that the put rights are exercised, in which case we will be in default of our obligations under our purchase agreement with Sovereign and the terms of the convertible preferred stock in our Articles of Incorporation. The exercise of any of these put rights would have a material adverse effect on our business and financial condition.

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other sources, which may also include the sale of certain of our oil and gas properties. Our ability to obtain financing or to sell our properties on favorable terms may be impaired by many factors outside of our control, including the capital markets (both generally and in the crude oil and natural gas industry in particular), our limited operating history, the location of our crude oil and natural gas properties and prices of crude oil and natural gas on the commodities markets (which will impact the amount of asset-based financing available to us) and other factors. Further, if crude oil or natural gas prices on the commodities markets decline, our revenues will likely decrease and such decreased revenues may increase our requirements for capital.

Any new debt or equity financing arrangements may not be available to us, or may be available only on unfavorable terms. Additionally, these alternatives could be highly dilutive to our existing shareholders, and may not provide us with sufficient funds to meet our long-term capital requirements. We have and may continue to incur substantial costs in the future in connection with raising capital to fund our business, including investment banking fees, legal fees, accounting fees, securities law compliance fees, printing and distribution expenses and other costs. We may also be required to recognize non-cash expenses in connection with certain securities we may issue, which may adversely impact our financial condition. If the amount of capital we are able to raise from financing activities, together with our revenues from operations, is not sufficient to satisfy our capital needs (even to the extent that we reduce our operations), we will be required to reduce operating costs, which could jeopardize our future strategic initiatives and business plans, and we may be required to sell some or all of our properties (which could be on unfavorable terms), seek joint ventures with one or more strategic partners, strategic acquisitions and other strategic alternatives, cease our operations, sell or merge our business, or file a petition for bankruptcy.

Our financial statements the quarter ended June 30, 2012 were prepared assuming we would continue as a going concern, which contemplates that we will continue in operation for the foreseeable future and will be able to realize assets and settle liabilities and commitments in the normal course of business. These financial statements do not include any adjustments to reflect the possible future effects on the recoverability and classification of assets or the amounts and classifications of liabilities that could result should we be unable to continue as a going concern.

Fair Value Measurements

Certain financial instruments and nonfinancial assets and liabilities, whether measured on a recurring or non-recurring basis, are recorded at fair value. A fair value hierarchy, established by U.S. GAAP, prioritizes the inputs used to measure fair value. The hierarchy gives the highest priority to unadjusted quoted prices in active markets for identical assets or liabilities (Level 1 measurements) and the lowest priority to unobservable inputs (Level 3 measurements).

Our financial instruments include cash and cash equivalents, trade receivables, trade payables, and notes payable to bank, all of which are considered to be representative of their fair market value, due to the short-term and highly liquid nature of these instruments.

As discussed in Note 4, we have incurred asset retirement obligations of $1,625,360, the value of which was determined using unobservable pricing inputs (or Level 3 inputs). We use the income valuation technique to estimate the fair value of the obligation using several assumptions and judgments about the ultimate settlement amounts, inflation factors, credit adjusted discount rates, and timing of settlement.

Our contingent consideration liability is also estimated using unobservable pricing inputs (or Level 3 inputs). We use a model to simulate the value of our future stock based on the historical mean of the stock price to estimate the fair value of the contingent consideration liability. We incurred the contingent consideration liability on October 20, 2011, in connection with the acquisition of assets from Sovereign and on that date the estimated value of the contingent consideration liability was nil. Subsequent changes in fair value resulted in a non-cash charge to operations amounting to $1,404,059 during 2011. During the period ended June 30, 2012, the change in value of the contingent consideration liability resulted in a non-cash loss amounting to $4,146,412 and the obligation was settled by issuing 21,350,247 shares of common stock to Sovereign on May 17, 2012.

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Full Cost Method of Accounting for Oil and Gas Properties

We have elected to utilize the full cost method of accounting for our oil and gas activities. In accordance with the full cost method of accounting, all costs associated with acquisition, exploration, and development of oil and gas reserves, including directly related overhead costs and related asset retirement costs, are capitalized into a cost center. Our cost centers consist of the Canadian cost center and the United States cost center.

All capitalized costs of oil and gas properties within each cost center, including the estimated future costs to develop proved reserves, are amortized on the unit-of-production method using estimates of proved reserves. Excluded from this amortization are costs associated with unevaluated properties, including capitalized interest on such costs. Unevaluated property costs are transferred to evaluated property costs at such time as wells are completed on the properties or management determines that these costs have been impaired.

Oil and gas properties without estimated proved reserves are not amortized until proved reserves associated with the properties can be determined or until impairment occurs. The cost of these properties is assessed quarterly, on a field-by-field basis, to determine whether the properties are recorded at the lower of cost or fair market value.

Sales of oil and gas properties are accounted for as adjustments of capitalized costs with no gain or loss recognized, unless such adjustments would significantly alter the relationship between capitalized costs and proved reserves of oil and gas, in which case the gain or loss is recognized in income. We have not sold any oil and gas properties through June 30, 2012.

Full Cost Ceiling Test

At the end of each quarterly reporting period, the cost of oil and gas properties in each cost center are subject to a “ceiling test” which basically limits capitalized costs to the sum of the estimated future net revenues from proved reserves, discounted at 10% per annum to present value, based on current economic and operating conditions, at the end of the period, plus the cost of properties not being amortized, plus the lower of cost or fair market value of unproved properties included in costs being amortized, less the income tax effects related to book and tax basis differences of the properties. If the cost of oil and gas properties exceeds the ceiling, the excess is reflected as a non-cash impairment charge to earnings. The impairment charge is permanent and not reversible in future periods, even though higher oil and gas prices in the future may subsequently and significantly increase the ceiling amount. No impairment charges were incurred during the periods ended June 30, 2012 and 2011.

Asset Retirement Obligation

We record the fair value of a liability for an asset retirement obligation in the period in which the asset is acquired and a corresponding increase in the carrying amount of the related long-lived asset if a reasonable estimate of fair value can be made. The associated asset retirement cost capitalized as part of the related asset is allocated to expense over the asset’s useful life. If the liability is settled for an amount other than the recorded amount, a gain or loss is recognized. The asset retirement obligation is recorded at its estimated fair value and accretion is recognized over time as the discounted liability is accreted to its expected settlement value. Fair value is determined by using the expected future cash outflows discounted at our credit-adjusted risk-free interest rate.

Oil and Gas Revenue Recognition

We use the sales method of accounting for oil and gas revenues. Under this method, revenues are recognized based on the actual volumes of gas and oil sold to purchasers at a fixed or determinable price, when delivery has occurred and title has transferred, and if collectability of the revenue is probable. Delivery occurs and title is transferred when production has been delivered to a purchaser’s pipeline or truck. The volume sold may differ from the volumes we are entitled to, based on our individual interest in the property. We utilize a third-party marketer to sell oil and gas production in the open market. As a result of the requirements necessary to gather information from purchasers or various measurement locations, calculate volumes produced, perform field and wellhead allocations and distribute and disburse funds to various working interest partners and royalty owners, the collection of revenues from oil and gas production may take up to 45 days following the month of production. Therefore, we may make accruals for revenues and accounts receivable based on estimates of our share of production. Since the settlement process may

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take 30 to 60 days following the month of actual production, our financial results may include estimates of production and revenues for the related time period. We will record any differences between the actual amounts ultimately received and the original estimates in the period they become finalized.

Stock-based compensation

We measure compensation cost for stock-based payment awards at fair value and recognizes it as compensation expense over the service period for awards expected to vest. Compensation cost is recorded as a component of general and administrative expenses in the consolidated statements of operations, net of an estimated forfeiture rate, and amounted to $708,343 for the period ended June 30, 2012. Compensation cost is only recognized for those awards expected to vest on a straight-line basis over the requisite service period of the award. Our policy is to issue new shares to fulfill the requirements for options that are exercised.

Earnings (Loss) Per Share

The computation of basic net loss per common share is based on the weighted average number of shares that were outstanding during the period, including contingently redeemable common stock. The computation of diluted net loss per common share is based on the weighted average number of shares used in the basic net loss per share calculation plus the number of common shares that would be issued assuming the exercise of all potentially dilutive common shares outstanding. As of June 30, 2012, potentially dilutive common shares include warrants to purchase 4,150,000 shares of common stock, options to purchase 2,840,000 shares of common stock, and preferred stock convertible into 1,700,000 shares of common stock. During the periods ended June 30, 2012 and 2011 potentially dilutive common shares were not included in the computation of diluted loss per shares as to do so would be anti-dilutive.

Income Taxes

We recognize income taxes on an accrual basis based on tax position taken or expected to be taken in its tax returns. A tax position is defined as a position in a previously filed tax return or a position expected to be taken in a future tax filing that is reflected in measuring current or deferred income tax assets and liabilities. Tax positions are recognized only when it is more likely than not (i.e., likelihood of greater than 50%), based on technical merits, that the position would be sustained upon examination by taxing authorities. Tax positions that meet the more likely than not threshold are measured using a probability-weighted approach as the largest amount of tax benefit that is greater than 50% likely of being realized upon settlement. Income taxes are accounted for using an asset and liability approach that requires the recognition of deferred tax assets and liabilities for the expected future tax consequences of events that have been recognized in our financial statements or tax returns. A valuation allowance is established to reduce deferred tax assets if all, or some portion, of such assets will more than likely not be realized. Should they occur, our policy is to classify interest and penalties related to tax positions as interest expense. Since our inception, no such interest or penalties have been incurred.

Concentration

During the six months ended June 30, 2012, sales of oil and gas to four customers individually exceeded 10% of the total oil and gas revenue. Sales to Husky Energy Marketing, BP Canada Energy, Kelly Maclaskey Oilfield Service Inc., and Gibson Petroleum accounted for approximately 36%, 16%, 13% and 12% of total oil and gas sales, respectively. We believe that the loss of any of the significant customers would not result in a material adverse effect on our ability to market future oil and natural gas production.

NOTE 3 - OIL AND GAS PROPERTIES

The amount of capitalized costs related to oil and gas property and the amount of related accumulated depletion, depreciation, and amortization are as follows:


	June 30, 2012			December 31, 2011
Proven property, net of impairment	$	9,090,866		$	8,992,793
Accumulated depletion, depreciation, and amortization		(1,288,580	)		(493,594	)

		7,802,286			8,499,199
Unproven property		8,363,852			8,335,380

	$	16,166,138		$	16,834,579

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NOTE 4 – ASSET RETIREMENT OBLIGATION

The following table reconciles the value of the asset retirement obligation for the periods ended June 30, 2012 and June 30, 2011:


	June 30, 2012			June 30, 2011
Opening balance, January 1	$	1,601,423		$	—
Liabilities incurred		—			—
Liabilities settled		—			—
Foreign currency translation adjustment		(2,003	)		—
Accretion expense		25,940			—

Ending balance, June 30	$	1,625,360		$	—

NOTE 5 - STOCKHOLDERS’ EQUITY

On February 2, 2011, we completed a private placement for 300,000 units at $0.50 per unit, for a total of $150,000 in gross proceeds, to one foreign investor residing outside of the United States. Each unit consisted of one share of restricted common stock and one warrant to purchase an additional share of common stock of the Company at $0.50 per share with a term of three years. This offering was exempt from registration pursuant to Regulation S under the Securities Act of 1933, as amended (rules governing offers and sales of securities made outside of the United States without registration). At the time of the sale of the units, the relative fair value of the common stock and the warrants was estimated to be $140,200 and $9,800, respectively, as determined based on the relative fair value allocation of the proceeds.

In April 2011, in order to attract additional investment capital, our two executive officers (Mr. Vandeberg and Mr. Diamond-Goldberg) and Mr. Wayne Gruden, a significant shareholder of the Company, surrendered a total of 15,890,000 shares of common stock owned by them to us, which shares were immediately cancelled.

On April 28, 2011, we completed a private placement for 250,000 units at $1.00 per unit, for a total of $250,000 in gross proceeds, to one foreign investor residing outside of the United States. Each unit consisted of one share of restricted common stock and one warrant to purchase an additional share of common stock at $1.00 per share with a term of three years. This offering was exempt from registration pursuant to Regulation S under the Securities Act of 1933, as amended. At the time of the sale of the units, the relative fair value of the common stock and the warrants was estimated to be $140,700 and $109,300, respectively, as determined based on the relative fair value allocation of the proceeds.

On August 10, 2011, we completed a private placement for 2,300,000 units at $2.00 per unit, for a total of $4,600,000 in gross proceeds. Each unit consists of one share of restricted convertible preferred stock and a warrant to purchase one share of restricted common stock. The convertible preferred stock is convertible into one share of restricted common stock, subject to customary adjustment for stock splits or similar events. The warrants are exercisable at $2.00 per share over a period of three years from the date of issuance. The offering was conducted under the exemption from registration provided pursuant to Regulation S under the U.S. Securities Act of 1933, as amended. The holders of shares of convertible preferred stock have a put right to require us to repurchase such

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shares for a price of $2.00 per share. The amount allocated to the convertible redeemable preferred stock is presented as mezzanine equity in the consolidated financial statements rather than as permanent equity. We allocated the gross proceeds of $4,600,000 from the private placement between the convertible preferred stock and the warrants issued proportionately based on their estimated fair values as of the closing date of the private placement. The relative fair value of the convertible preferred stock and the warrants was estimated to be $2,766,733 and $1,833,267, respectively. The effective conversion price was used to measure the intrinsic value of the embedded conversion option which amounted to $2,270,266. As a result, the carrying value of the convertible preferred stock presented as mezzanine equity in the consolidated financial statements (net of the impact of the conversion of 600,000 shares on convertible preferred stock described below) is $366,953. As of December 31, 2011 and June 30, 2012, no adjustment to the carrying value of the convertible preferred stock to its redemption value was necessary as it was not considered probable that the convertible preferred stock would become redeemable (as described below, the holders of the convertible preferred stock conditionally agreed to waive their put rights). At June 30, 2012, the aggregate redemption value is $3.4 million.

On September 28, 2011, we entered into a retainer letter agreement with Midsouth Capital Inc., an investment banking firm, for investment banking services. As part of the compensation to Midsouth, we issued 10,000 shares of restricted common stock to Midsouth.

On October 21, 2011, we issued 3,552,516 common shares per share to Sovereign in connection with our acquisition of the Canadian oil and gas properties. Sovereign has a put right to require us to repurchase such shares for a price of $2.00 per share. Sovereign executed a stand-still agreement that nullified their put rights until various conditions could be met, most significantly the joint effort by the Company and Sovereign to dispose, by sale to unrelated parties, of the 3,552,516 shares issued to Sovereign on the closing of the asset acquisition. In connection with the acquisition of assets from Sovereign, the Company agreed to a mechanism of staggered payments to maintain the value of the stock component of the purchase at the original amount of $2.00 per share through a series of Variable Weighted Average Price (“VWAP”) calculations. Under the purchase agreement, Sovereign could not own more than 10% of the Company’s common stock, unless they chose to waive that condition. On May 17, 2012, in conjunction with the final VWAP calculation, Sovereign waived the 10% ownership limitation and the Company issued 21,350,247 shares of restricted common stock to Sovereign. The contingent consideration obligation was settled and a loss of $4,146,412 was recognized to reflect the difference between the contingent consideration and the fair value of the final VWAP shares. The 21,350,247 shares of common stock issued to Sovereign on May 17, 2012, also include a put right, whereby Sovereign may require us to repurchase the shares for a price of $2.00 per share therefore, the redemption amount of the common stock is recorded as mezzanine equity.

On January 12, 2012, we issued 60,000 shares of common stock with a fair value of $60,000 to a consultant in exchange for services. The fair value of the common shares was recorded as a component of general administrative expenses during the period ended March 31, 2012.

On March 26, 2012 the holders of convertible preferred stock agreed to waive their put option, with the condition that Sovereign also waives its put option. In connection with the waiver by the holders of the convertible preferred stock, the Company agreed to issue 2,772,728 shares of common stock to the convertible preferred stock holders as consideration for the waivers and only following a similar waiver by Sovereign. No such shares have been issued to date. Sovereign chose not to waive its put option rights, but rather executed a stand-still agreement that nullified their put rights until various conditions could be met, most significantly the joint effort by the Company and Sovereign to dispose, by sale to unrelated parties, of the 3,552,516 shares issued to Sovereign on the closing of the asset acquisition. The stand-still agreement was effective through June 15, 2012, and the Company and Sovereign have reached a verbal agreement to extend the stand-still agreement while the parties continue their joint efforts to dispose of the shares. Upon achieving the sale of these original shares, the Company expects that Sovereign will then permanently waive its put option rights.

On March 30, 2012, a preferred stock holder elected to convert its preferred shares to common stock. Accordingly, the Company issued 600,000 shares of common stock and retired 600,000 preferred shares. Mezzanine equity was reduced by $129,514, and then transferred to common shares and additional paid-in capital accordingly.

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On May 22, 2012, the Company commenced an agreement with Lincoln Park Capital to sell up to $10.2 million in common stock during a term of three years. Upon signing the agreements, Lincoln Park made an initial purchase of 192,308 shares of common stock for $50,000 at a price of $0.26 per share. Upon filing the registration statement, Lincoln Park purchased another $50,000 at a price of $0.23 per share. On June 29, 2012 the SEC declared effective the registration statement related to the transaction, at which time Lincoln Park purchased an additional $100,000 in common stock at $0.165 per share (recorded as stock subscription receivable at June 30, 2012). In consideration for entering into the Purchase Agreement, the Company issued 723,592 shares of common stock to Lincoln Park as an initial commitment fee. The fair value of these 723,592 commitment shares were recorded as deferred offering costs and amounted to $208,311. The deferred offering costs will be amortized as we utilize the purchase agreement with Lincoln Park. Up to 1,072,183 of additional shares of common stock may be issued on a pro rata basis to LPC as an additional commitment fee as Lincoln Park purchases additional shares of common stock under the Purchase Agreement. The Company received $100,000 from Lincoln Park on July 3, 2012.

Warrants

The following table summarizes outstanding warrants to purchase shares of our common stock as of December 31, 2011 and June 30, 2012, as described above:


	Shares of Common Stock Issuable from Warrants Outstanding as of
Date of Issue	June 30, 2012		December 31, 2011		Exercise Price		Expiration
October 2010		1,300,000		1,300,000	$	0.50		October 2013
February 2011		300,000		300,000	$	0.50		February 2014
April 2011		250,000		250,000	$	1.00		April 2014
August 2011		2,300,000		2,300,000	$	2.00		August 2014

		4,150,000		4,150,000

As of June 30, 2012, none of the outstanding warrants had been exercised.

Stock Incentive Plan

On May 3, 2011, our Board of Directors adopted the Legend Oil and Gas, Ltd. 2011 Stock Incentive Plan (“Plan”). The Plan provides for the grant of options to purchase shares of our common stock, and stock awards consisting of shares of our common stock, to eligible participants, including directors, executive officers, employees and consultants of the Company. We have reserved 4,500,000 shares of common stock for issuance under the Plan. In November 2011, our Board approved the grant of stock options for a total of 1,400,000 shares to two Directors and two employees at an exercise price of $2.17 per share. The fair value of the option grant was estimated at the date of the grant using the Black-Scholes option pricing model with the following assumptions: expected volatility of 94.18%, a risk free rate of 2.03%, and an expected life of 10 years. In December 2011, the Board approved the grant of stock options for a total of 1,400,000 shares to two directors and two employees at an exercise price of $0.99 per share. The fair value of the option grant was estimated at the date of the grant using the Black-Scholes option pricing model with the following assumptions: expected volatility of 92.9%, a risk free rate of 1.92%, and an expected life of 10 years. In February 2012, the Board approved the grant of stock options for a total of 40,000 shares to two directors at an exercise price of $0.87 per share. The fair value of the option grant was estimated at the date of the grant using the Black-Scholes option pricing model with the following assumptions: expected volatility of 92.9%, a risk free rate of 2.00%, and an expected life of 10 years.

At June 30, 2012, there were 1,660,000 shares of common stock available under the Plan, and there were options to purchase 973,333 shares of stock exercisable, with a remaining contractual term of 9.5 years. The weighted average exercise price of stock options granted and exercisable at June 30, 2012 was $1.57. There were no options exercised, forfeited, or expired during the period ended June 30, 2012.

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At June 30, 2012, the aggregate intrinsic value of outstanding stock options was $0. Intrinsic value is the total pretax intrinsic value for all “in-the-money” options (i.e., the difference between the Company’s closing stock price on June 30, 2012 and the exercise price, multiplied by the number of shares) that would have been received by the option holders had all option holders exercised their options as of June 30, 2012. This amount changes based on the fair market value of the Company’s stock.

At June 30, 2012, the Company had $1.9 million of total unrecognized compensation cost related to unvested stock options, which is expected to be recognized over a weighted average period of 1.4 years.

NOTE 6 – NOTE PAYABLE TO BANK

Under a series of agreements with National Bank of Canada (the “Bank”), as of June 30, 2012, we had a revolving credit facility with a maximum borrowing base of $3,928,800 (CA$4,000,000) through our wholly-owned subsidiary, Legend Canada. Outstanding principal under the loan bears interest at a rate equal to the Bank’s prime rate of interest (currently 3%) plus 1%. We are obligated to pay a monthly fee of 0.25% of any undrawn portion of the credit facility. The borrowings under the credit facility are payable upon demand at any time. Borrowings under the agreements are collateralized by a Fixed and Floating Charge Demand Debenture (the “Debenture”) to the Bank in the face amount of CA$25 million, to secure payment of all debts and liabilities owed by Legend Canada to the Bank. The interest rate on amounts drawn under the Debenture, as well as interest that is past due, is the prime rate, plus 7% per annum. As further collateral, Legend Canada also executed an Assignment of Book Debts on October 19, 2011, that grants, transfers and assigns to the Bank a continuing and specific security interest in specific collateral of Legend Canada, including all debts, proceeds, accounts, claims, money and chooses in action which currently or in the future are owing to Legend Canada. Under the agreements, we must maintain a working capital ratio, exclusive of bank indebtedness, of at least 1 to 1. For purposes of this calculation, the undrawn availability under the revolving credit facility is added to current assets. We were in compliance with this debt covenant at June 30, 2012. The revolving credit facility is subject to review by the Bank at future dates as determined by the Bank, and the Bank may increase or lower the maximum borrowing base subject to their review.

The Company also had a bridge demand loan in place through Legend Canada that was fully drawn on June 30, 2012 for $1,473,330 (CA$1,500,000). This bridge facility bears interest at a rate equal to the Bank’s prime rate of interest (currently 3%) plus 2%. On June 5, 2012, the Company entered into an agreement with National Bank to repay this bridge demand loan with 5 monthly payments of CA$250,000 commencing July 15, 2012, with final repayment on December 1, 2012. The Company made the first scheduled payment of CA$250,000 to the Bank on July 15, 2012.

As of June 30, 2012, there was $5,323,590 (CA$5,420,067) in total indebtedness with National Bank outstanding on a combination of the revolving credit facility and bridge facility. The next scheduled review of the revolving credit facility is December 1, 2012.

Legend Canada also has a CA$20,000 ($20,000USD) letter of guarantee outstanding, related to a company that provides third party processing to the Company.

NOTE 7 – SUBSEQUENT EVENT

From July 1, 2012, through the date of this Report, the Company sold an additional 1,000,000 shares of common stock under its agreement with Lincoln Park for gross proceeds of $154,000. See Note 5 regarding the Lincoln Park agreement. The Company issued 16,267 additional commitment shares in conjunction with these sales. At the date of this report, the remaining registered shares to be issued under the agreement for cash amounted to 7,480,962 and the remaining additional commitment shares to be issued under the agreement amounted to 1,040,071.

On July 26, 2012, the Company agreed to sell its oil and gas interests in the Red Earth area of Alberta, Canada for gross proceeds, before costs of sale, of CA$750,000. This transaction is expected to close on or about August 7, 2012. The net proceeds from the sale of the Red Earth interests will be credited to the Company’s Canadian full cost pool with no gain or loss recognized. At December 31, 2011, the discounted future net cash flows associated with the Red Earth interest amounted to CA$537,000.

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ITEM 2

MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS

The following discussion and analysis is based upon our consolidated financial statements, which have been prepared in accordance with accounting principles generally accepted in the United States, and should be read in conjunction with our financial statements and related notes. We incorporate by reference into this Report our audited consolidated financial statements for the years ended December 31, 2011 and 2010. The preparation of these financial statements requires management to make estimates and assumptions that affect the reported amounts of assets, liabilities, revenue and expenses, and related disclosure of contingent assets and liabilities. Management bases its estimates on historical experience and on various other assumptions that are believed to be reasonable under the circumstances, the results of which form the basis for making judgments about the carrying values of assets and liabilities that are not readily apparent from other sources. Actual results may differ from these estimates under different assumptions or conditions. In addition, the following discussion and analysis contains forward-looking statements that involve risks and uncertainties, including, but not limited to, those discussed in “Forward Looking Statements,” and elsewhere in this Report.

The following management’s discussion and analysis is intended to assist in understanding the principal factors affecting our results of operations, liquidity, capital resources and contractual cash obligations. This discussion should be read in conjunction with our consolidated financial statements which are incorporated by reference herein, information about our business practices, significant accounting policies, risk factors, and the transactions that underlie our financial results, which are included in various parts of this filing.

For ease of presentation in the following discussions of “Comparison of Results” and “Liquidity and Capital Resources”, we round dollar amounts to the nearest thousand dollars (other than average prices per barrel and per share amounts).

Overview of Business

Our business focus is to acquire producing and non-producing oil and gas right interests and develop oil and gas properties that we own or in which we have a leasehold interest. We also anticipate pursuing the acquisition of leaseholds and sites within other geographic areas that meet our general investment guidelines and targets. The majority of our operational duties are outsourced to consultants and independent contractors, including for drilling, maintaining and operating our wells, and we maintain a limited in-house employee base.

On October 20, 2011, our wholly-owned subsidiary, Legend Canada completed the acquisition of the majority of the petroleum and natural gas leases, lands and facilities held by Sovereign. The assets acquired consisted of substantially all of Sovereign’s assets, including interests in producing oil and gas leasehold properties in Western Canada that have been maintained through the drilling of internally generated low to medium risk exploration and development sites. The principal natural gas leasehold properties are located in Medicine River and Berwyn in Alberta, and Clarke Lake in British Columbia. The assets also include an interest in various light oil properties located in Red Earth and Swan Hills in Alberta, and in Inga in British Columbia.

Our company was incorporated under the laws of the State of Colorado on November 27, 2000 under the name “SIN Holdings, Inc.” On November 29, 2010, we changed our name to Legend Oil and Gas, Ltd. Our only subsidiary is Legend Canada, which was formed in Alberta, Canada on July 28, 2011 to acquire the Sovereign assets. Neither we nor Legend Canada are reporting issuers in any province of Canada.

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Results of Operations

The following is a discussion of our consolidated results of operations, financial condition and capital resources. You should read this discussion in conjunction with our Consolidated Financial Statements and the Notes thereto contained elsewhere in this Form 10-Q. Comparative results of operations for the periods indicated are discussed below.

The following table sets forth certain of our oil and gas operating information for the three and six months ended June 30, 2012, and June 30, 2011, respectively.


	Three Months Ended June 30,				Six Months Ended June 30,
	2012		2011		2012		2011
Production Data:
Oil production (bbls)		5,402		512		11,230		1,045
Average daily oil production (bbl/d)		59		6		62		6
Natural gas production (mcf)		82,958		—		175,397		—
Average daily natural gas production (mcf/d)		912		—		964		—
Natural gas liquids production (bbl)		457		—		878		—
Average daily natural gas liquids production (bbl/d)		5		—		5		—
Total BOE		19,685		512		41,341		1,045
Total BOE/d		216		6		227		6

Revenue Data:
Oil revenue ($)		443,000		50,000		947,000		96,000
Average realized oil sales price ($/bbl)		82.05		97.22		84.46		91.49
Gas revenue ($)		118,000		—		284,000		—
Average realized gas sales price ($/mcf)		1.46		—		1.61		—
Natural gas liquids revenue ($)		27,000		—		55,000		—
Average realized natural gas liquids price ($/bbl)		59.42		—		63.32		—

Operating expenses:
Lease operating expenses		423,000		49,000		851,000		83,000
Average operating expenses ($/boe)		21.49		95.68		20.59		79.43

Operating Margin ($/boe)		8.38		1.54		10.52		12.06

Depreciation, depletion, and amortization		382,000		20,000		803,000		20,000

*	*Oil and natural gas were combined by converting natural gas to oil equivalent on the basis of 6 mcf of gas = 1 boe*.

Production and Revenue

Revenues


	Three months Ended June 30,						Six Months Ended June 30,
	2012 $		2011 $		Change %		2012 $		2011 $		Change %
Product revenues:
Crude oil sales		443,000		50,000		786		947,000		96,000		888
Natural gas sales		118,000		—		—		284,000		—		—
Natural gas liquids sales		27,000		—		—		55,000		—		—

Product revenues		588,000		50,000		1,076		1,286,000		96,000		1,240

The increase in natural gas and natural gas liquids are the result of the Canadian asset acquisition in the fourth quarter of 2011. Oil sales in our Kansas property increased from $50,000 in the second quarter of 2011 to $96,000 in the second quarter of 2012, and increased from $96,000 to $219,000 in the six months ended June 30, 2011 compared to the six months ended June 30, 2012. The remaining increase in oil revenues is the result of adding the Canadian properties in October 2011.

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Production


	Three Months Ended June 30,						Six Months Ended June 30,
	2012		2011		Change %		2012		2011		Change %
Sales Volume:
Crude Oil(bbl)		5,402		512		955		11,230		1,045		975
Natural Gas(mcf)		82,958		—		—		175,397		—		—
Natural Gas Liquids(bbl)		457		—		—		878		—		—

Total BOE		19,685		512		3,745		41,341		1,045		3,856

*	*Oil and natural gas were combined by converting natural gas to oil equivalent on the basis of 6 mcf of gas = 1 boe*.

The overall increase in production was mostly related to the Canadian asset acquisition. The Kansas property oil production is doubled year over year (512 bbls in 2011 compared to 1,067 in 2012, while the Canadian properties added 4,335bbls (48bbl/d) of oil production in the second quarter of 2012. All of the natural gas and natural gas liquids are from the Canadian properties that were added in the fourth quarter of 2011.

Commodity Prices Realized


	Three Months Ended June 30,							Six Months Ended June 30,
	2012 $		2011 $		Change %			2012 $		2011 $		Change %
Sales Price:
Crude Oil($/bbl)		82.05		97.22		(13	)		84.46		91.49		(8	)
Natural Gas($/mcf)		1.46		—		—			1.61		—		—
Natural Gas Liquids($/bbl)		59.42		—		—			63.32		—		—

The average price per barrel of crude oil during the second quarter of 2012 was $82.05, down from $97.22 in the second quarter of 2011, a decrease in price that mirrors the world oil pricing environment. The commodity pricing for the first half of 2012 has been relatively flat to date, with small decreases in prices year to date. We have no comparison price for the gas and NGL revenue as they are from the Canadian assets acquired in the fourth quarter of 2011. The prices we receive for our oil and natural gas production are determined by the market and heavily influence our revenue, profitability, access to capital and future rate of growth.

Lease Operating Expenses

Operating expenses increased on an absolute basis to $423,000 in the second quarter of 2012 from $49,000 in the second quarter of 2011. However, on a per barrel basis, the operating expense decreased from $95.68/boe in the second quarter of 2011 to $21.49/boe in the corresponding period of 2012. A major charge in the second quarter was for an unscheduled workover of our Swan Hills property that increased our expenses. For the six month period, the operating expenses totaled $851,000($20.59/bbl), compared to $83,000($79.43/bbl) for the comparative period in 2011.

General and Administrative Expenses

General and administrative expenses include: professional fees; management fees; travel expenses; office and administrative expenses; and marketing and SEC filing expenses. General and administrative expenses were $912,000 for the second quarter of 2012, as compared to $104,000 for the same period in 2011, an $808,000 increase. The period-to-period increase is largely a result of the increased size and scope of the Company following the 2011 Sovereign purchase, and structuring for future growth opportunities. More particularly, the increase is due to: (i) an increase in compensation paid to our executive officers; (ii) an increase in fees paid to professionals in connection with restructuring the business and related matters; (iii) paying contract personnel to assist with our operations; and (iv) an increase in SEC reporting activity and expenses.

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	Three months Ended June 30,						Six Months Ended June 30,
	2012 $		2011 $		Change %		2012 $		2011 $		Change %
General and administrative expenses
Professional fees		192,000		42,000		357		445,000		95,000		368
Salaries and benefits		196,000		41,000		378		431,000		81,000		432
Office and administration		185,000		21,000		781		339,000		50,000		578
Stock based compensation		339,000		—		—		708,000		—		—

Total		912,000		104,000		777		1,923,000		226,000		751

The second quarter of 2012 saw salary and benefits and professional fee expenses decrease from the first quarter of 2012 as the Company worked to reduce costs and streamline internal operations. The decreases in salaries and professional fees were slightly offset by increased administration costs, mostly in the form of software licenses. Stock based compensation is a significant item in the general and administrative, and the amount in the first two quarters of 2012 reflects the amortization of the fair value of options granted in 2011 and the addition of options granted in 2012 to new directors. Disclosure of these stock based compensation transactions can be found in Note 5 to the Notes to Consolidated Financial Statements for the period ended June 30, 2012.

Depletion, depreciation, and amortization

The company incurred $382,000 for depreciation, depletion, amortization for the three months ended June 30, 2012 ($20,000 for three months ended June 30, 2011) and $803,000 for the six months ended June 30, 2012 ($20,000 for six months ended June 30, 2011). The increase for the periods presented is due to an increase in production.

Accretion expense

For the three months ended June 30, 2012 the company had accretion expense of $13,000 (nil in 2011) related to the Company’s asset retirement obligations. For the six months ended June 30, 2012, the accretion expense totaled $26,000(nil in 2011). The increases are the result of higher average obligations in 2012 as our asset base has grown in these periods.

Interest expense

Interest expense was $57,000 and $114,000 for the three and six months ended June 30, 2012 respectively (nil in 2011). The increase in interest expenses from 2011 is due to the establishment of the revolving bank line in Canada, and the subsequent interest payments from having drawn on this line. There was no bank indebtedness in the first six months of 2011.

Change in contingent consideration

Due to the nature of the security related price guarantee in conjunction with the International Sovereign Canadian asset purchase in October 2011, there was deemed to be contingent consideration and subsequent changes in fair value of this consideration. The amount of this consideration obligation was reduced to $0 at June 30, 2012 as a result of the Company issuing additional shares to Sovereign ($1,361,000 at March 31, 2012; $1,404,000 at December 31, 2011). Disclosure of the contingent consideration related to those stock issuances can be found in Note 5 to the Notes to Consolidated Financial Statements for the period ended June 30, 2012, which is incorporated by reference herein.

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Net loss

The company recorded a net loss of $5,388,348 and $6,577,313 in the three and six months ended June 30, 2012, as compared to the net losses of $123,000 and $232,000 in the corresponding periods in 2011. The increase in the loss, offset by an increase in revenue due to the increased production levels, is mainly due to the addition of stock based compensation in 2012, a large expense for the contingent consideration related to the Sovereign asset purchase, higher operating expenses associated with the higher production levels, the increase in general and administrative costs associated with the growth in the company, and increased depletion charges in 2012.

Liquidity and Capital Resources

Liquidity

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Subsequent to June 30, 2012, and discussed in Note 7, the Company agreed on July 26, 2012 to sell its oil and gas interests in the Red Earth, Alberta property for CA$750,000 in gross proceeds. This transaction is expected to close on or about August 7, 2012. The revolving bank line borrowing base will be reduced by CA$150,000 as a result of this sale. It is management’s intention to use the remaining net proceeds, after the costs of the sale, for the next scheduled monthly bridge loan payment and to retire current liabilities in working capital. From time to time, we may seek to sell certain of our other oil and gas properties.

In the event that we are able to resolve our obligations to the Bank and the put rights, we anticipate needing additional financing to fund our drilling and development plans in 2012. As described above, we have entered into an agreement with Lincoln Park to sell up to $10.2 million in common stock. However, the timing for closing on funds is variable and there is no guarantee on the amount of proceeds we will receive. We may seek financing from other sources, which may also include the sale of certain of our oil and gas properties. Our ability to obtain financing or to sell our properties on favorable terms may be impaired by many factors outside of our control, including the capital markets (both generally and in the crude oil and natural gas industry in particular), our limited operating history, the location of our crude oil and natural gas properties and prices of crude oil and natural gas on the commodities markets (which will impact the amount of asset-based financing available to us) and other factors. Further, if crude oil or natural gas prices on the commodities markets decline, our revenues will likely decrease and such decreased revenues may increase our requirements for capital.

-23-

Cash Flows

The following table summarizes our cash flows for the periods ended June 30, 2012 and June 30, 2011, respectively:


	For the six months ended June 30,
	2012			2011
Net cash used in operating activities	$	(168,000	)	$	(175,000	)
Net cash used in investing activities		(142,000	)		(172,000	)
Net cash provided by financing activities		320,000			400,000
Effect of exchange rate changes		9,000			—

Net change in cash during period		19,000			53,000

Cash from Operating Activities

Cash used in operating activities was $168,000 for the six months ended June 30, 2012, as compared to cash used by operating activities of $175,000 in the three months ended June 30, 2011. The slight decrease in cash used reflects the consistent operational base of the Company’s assets and stabilization of the Sovereign assets that were added in the fourth quarter of 2011.

Cash from Investing Activities

Cash used for investing activities for the six months ended June 30, 2012 was $142,000 as compared to $172,000 during the six months ended June 30, 2011. The slight decrease is due to the Company spending much of 2012 integrating the Sovereign assets and weathering a poor pricing environment, whereas in the first six months of 2011 the Company was making continuing incremental investments in increasing its oil and gas activities.

Cash from Financing Activities

Total net cash provided by financing activities was $320,000 for the six months ended June 30, 2012, which is a combination of stock issuances to Lincoln Park Capital and the proceeds from bank financing. Total net cash provided by financing activities in the six months ended June 30, 2011 was in the form of common stock and warrants issuances in 2011.

Planned Capital Expenditures

As funds allow, we plan to resume our drilling program on the Kansas properties. In the first quarter of 2012 we finished the 2011 fourth quarter drilling program. Based on the encouraging results from this late 2011 drilling and early 2012 activity, we intend to execute a development program over the remainder of 2012 in the Kansas property.

With respect to the Canadian assets that we acquired in 2011, we have identified two low-risk drilling locations on the Swan Hills, Alberta property, which is currently being developed with one producing vertical oil well. We anticipate that well costs would be approximately $4 million per well. It is our intent to drill the first of these wells upon securing the financing necessary to proceed. We also anticipate potentially drilling at minimum one oil well on the Inga, British Columbia property, with drilling costs there expected to be approximately $1 million per well.

Off Balance Sheet Arrangements

We have no off-balance sheet arrangements.

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ITEM 3 DEFAULTS UPON SENIOR SECURITIES

None.

ITEM 4 CONTROLS AND PROCEDURES

Evaluation of Disclosure Controls and Procedures

Our management evaluated, with the participation of our President and our Chief Financial Officer, the effectiveness of the design and operation of our disclosure controls and procedures (as defined in Rules 13a-15(e) and 15d-15(e) under the Securities Exchange Act of 1934, as amended) as of the end of the period covered by this Report. Based on this evaluation, our President and our Chief Financial Officer concluded that our disclosure controls and procedures are effective to ensure that information we are required to disclose in reports that we file or submit under the Securities Exchange Act of 1934, as amended, (i) is recorded, processed, summarized and reported within the time periods specified in the Securities and Exchange Commission’s rules and forms, and (ii) is accumulated and communicated to our management, as appropriate, to allow timely decisions regarding required disclosure. Our disclosure controls and procedures include components of our internal control over financial reporting and, as such, are designed to provide reasonable assurance that such information is accumulated and communicated to our management. Management’s assessment of the effectiveness of our internal control over financial reporting is expressed at the level of reasonable assurance that the control system, no matter how well designed and operated, can provide only reasonable, but not absolute, assurance that the control system’s objectives will be met (see the section below in this Item 4 entitled Limitations on the Effectiveness of Internal Controls).

Changes in Internal Controls Over Financial Reporting

There have been no changes in our internal controls over financial reporting (as defined in Rules 13a-15(f) and 15d-15(f) of the Securities Exchange Act of 1934, as amended) that occurred during the three months ended June 30, 2012, that have materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.

Limitations on the Effectiveness of Internal Controls

Our management does not expect that our disclosure controls and procedures or our internal controls over financial reporting will necessarily prevent all fraud and material error. Our disclosure controls and procedures are designed to provide reasonable assurance of achieving our objectives and our President and Chief Financial Officer concluded that our disclosure controls and procedures are effective at that reasonable assurance level. Further, the design of a control system must reflect the fact that there are resource constraints, and the benefits of controls must be considered relative to their costs. Because of the inherent limitations in all control systems, no evaluation of controls can provide absolute assurance that all control issues and instances of fraud, if any, within the Company have been detected. These inherent limitations include the realities that judgments in decision-making can be faulty, and that breakdowns can occur because of simple error or mistake. Additionally, controls can be circumvented by the individual acts of some persons, by collusion of two or more people, or by management override of the internal control. The design of any system of controls is also based in part upon certain assumptions about the likelihood of future events, and there can be no assurance that any design will succeed in achieving its stated goals under all potential future conditions. Over time, control may become inadequate because of changes in conditions, or the degree of compliance with the policies or procedures may deteriorate.

PART II - OTHER INFORMATION

ITEM 5 OTHER INFORMATION

The Company agreed on July 26, 2012 to sell its oil and gas interests in the Red Earth, Alberta property for CA$750,000 in gross proceeds. The Company entered into a Royalty and General Rights Conveyance agreement for the sale dated August 7, 2012, a copy of which is filed as Exhibit 10.1 to this Report. This transaction is expected to close on or about August 7, 2012. See Note 7 in our Notes to Consolidated Financial Statements in this Report.

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ITEM 6 EXHIBITS

The exhibits listed in the accompanying index to exhibits are filed or incorporated by reference as part of this Report.

Certain of the agreements filed as exhibits to this Report contain representations and warranties by the parties to the agreements that have been made solely for the benefit of the parties to the agreement. These representations and warranties:

•

may have been qualified by disclosures that were made to the other parties in connection with the negotiation of the agreements, which disclosures are not necessarily reflected in the agreements;

•

may apply standards of materiality that differ from those of a reasonable investor; and

•

were made only as of specified dates contained in the agreements and are subject to subsequent developments and changed circumstances.

Accordingly, these representations and warranties may not describe the actual state of affairs as of the date that these representations and warranties were made or at any other time. Investors should not rely on them as statements of fact.

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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.


	LEGEND OIL AND GAS, LTD.

Dated: August 8, 2012	By:	/s/ Marshall Diamond-Goldberg
		Marshall Diamond-Goldberg
		President and Chief Executive Officer
		(Principal Executive Officer)

Dated: August 8, 2012	By:	/s/ Kyle Severson
		Kyle Severson
		Chief Financial Officer
		(Principal Accounting and Financial Officer)

-27-

EXHIBIT INDEX


Exhibit No.	Description	Location

10.1	Royalty and General Rights Conveyance, dated August 7, 2012, between Legend Energy Canada Ltd. and Range Royalty Limited Partnership	Incorporated by reference to Exhibit 99 to the Form 8-K filed by the Company on August 10, 2012.

31.1	Certification of Principal Executive Officer pursuant to Rule 13a-14(a) or Rule 15d-14(a) under the Securities Exchange Act of 1934	Filed herewith.

31.2	Certification of Principal Accounting and Financial Officer pursuant to Rule 13a-14(a) or Rule 15d-14(a) under the Securities Exchange Act of 1934	Filed herewith.

32.1	Certification of Principal Executive Officer and Principal Accounting and Financial Officer pursuant to Rule 13a-14(b) or 15d-14(b) under the Securities Exchange Act of 1934 and to 18 U.S.C. Section 1350	Filed herewith.

101.INS	XBRL Instance Document	**

101.SCH	XBRL Taxonomy Extension Schema Document	**

101.CAL	XBRL Taxonomy Extension Calculation Linkbase Document	**

101.LAB	XBRL Taxonomy Extension Label Linkbase Document	**

101.PRE	XBRL Taxonomy Extension Presentation Linkbase Document	**

101.DEF	XBRL Taxonomy Extension Definition Linkbase Document	**

XBRL (Extensible Business Reporting Language) information is furnished and not filed or a part of a registration statement or prospectus for purposes of Sections 11 or 12 of the Securities Act of 1933, as amended, is deemed not filed for purposes of Section 18 of the Securities Exchange Act of 1934, as amended, and otherwise is not subject to liability under these sections.

Large accelerated filer

Accelerated filer

Non-accelerated filer

Smaller reporting company