Edgar Filing: CROSS BORDER RESOURCES, INC.

xbor-10q_033112.htm

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q

(Mark One)

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

For the quarterly period ended March 31, 2012

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

For the transition period from ________to ________

COMMISSION FILE NUMBER 000-52738

CROSS BORDER RESOURCES, INC.

(Exact name of registrant as specified in its charter)

NEVADA		98-0555508
(State or other jurisdiction of incorporation or organization)		(I.R.S. Employer Identification No.)

22610 US Highway 281 N., Suite 218
San Antonio, TX		78258
(Address of principal executive offices)		(Zip Code)

(210) 226-6700

(Registrant's telephone number, including area code)

(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.

x Yes o 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).

x Yes o 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 o	Accelerated filer o
Non-accelerated filer o (Do not check if a smaller reporting company)	Smaller reporting company x

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act).

o Yes x No

Indicate the number of shares outstanding of each of the issuer's classes of common stock, as of the latest practicable date:

As of May 9, 2012, the Registrant had 16,151,946 shares of common stock outstanding.

Cross Border Resources, Inc.

INDEX

			Page of
			Form 10-Q
PART I.	FINANCIAL INFORMATION

	ITEM 1.	FINANCIAL STATEMENTS

		Condensed Balance Sheets as of March 31, 2012 (unaudited) and December 31, 2011	1

		Unaudited Condensed Statements of Operations for the three months ended March 31, 2012 and 2011	3

		Unaudited Condensed Statements of Cash Flows for the three months ended March 31, 2012 and 2011	4

		Notes to Unaudited Condensed Financial Statements	5

	ITEM 2.	MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS	17

	ITEM 3.	QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK	23

	ITEM 4.	CONTROLS AND PROCEDURES	23

PART II.	OTHER INFORMATION		24

	ITEM 1.	LEGAL PROCEEDINGS	24

	ITEM 1A.	RISK FACTORS	25

	ITEM 2.	UNREGISTERED SALES OF EQUITY SECURITIES AND USE OF PROCEEDS	30

	ITEM 6.	EXHIBITS	30

SIGNATURES			31

PART I - FINANCIAL INFORMATION

ITEM 1. FINANCIAL STATEMENTS

The accompanying unaudited financial statements have been prepared in accordance with the instructions to Form 10-Q and Article 8-03 of Regulation S-X, and, therefore, do not include all information and footnotes necessary for a complete presentation of financial position, results of operations, cash flows, and stockholders' equity in conformity with generally accepted accounting principles. In the opinion of management, all adjustments considered necessary for a fair presentation of the results of operations and financial position have been included and all such adjustments are of a normal recurring nature. Operating results for the three-month period ended March 31, 2012 are not necessarily indicative of the results that can be expected for the year ending December 31, 2012.

As used in this Quarterly Report on Form 10-Q, the terms "we,” "us,” "our,” and the “Company” mean Cross Border Resources, Inc. unless otherwise indicated. All dollar amounts in this Quarterly Report are in U.S. dollars unless otherwise stated.

Cross Border Resources, Inc.

Balance Sheets

	March 31,			December 31,
	2012			2011
	(Unaudited)
ASSETS

Current Assets:
Cash and cash equivalents	$	70,412		$	472,967
Accounts receivable - production		2,905,931			1,184,544
Prepaid expenses and other current assets		1,061,393			1,808,944
Current tax asset		21,737			21,737
Total Current Assets		4,059,473			3,488,192
Property and Equipment
Oil and gas properties (successful efforts method)		36,288,899			30,540,978
Less accumulated depletion and depreciation		(10,415,884	)		(9,870,830	)
Net Property and Equipment		25,873,015			20,670,148

Other Assets:
Other property and equipment, net of accumulated depreciation of $134,408 and $ 126,473 in 2012 and 2011, respectively		88,053			95,988
Deferred bond costs, net of accumulated amortization of $503,854 and $344,300 in 2012 and 2011, respectively		-			159,554
Deferred bond discount, net of accumulated amortization of $186,560 and $127,483 in 2012 and 2011, respectively		-			59,077
Deferred financing costs, net of accumulated amortization of $39,739 and $26,355 in 2012 and 2011, respectively		174,887			64,746
Intangible assets, net of accumulated amortization of $247,020 and $197,616 in 2012 and 2011, respectively		1,729,137			1,778,541
Goodwill		1,395,807			1,395,807
Other		54,324			54,324
Total Other Assets		3,442,208			3,608,037

TOTAL ASSETS	$	33,374,696		$	27,766,377

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

	March 31,			December 31,
	2012			2011
	(Unaudited)
LIABILITIES AND STOCKHOLDERS’ EQUITY

Current Liabilities:
Accounts payable - trade	$	1,081,770		$	103,759
Accounts payable - revenue distribution		236,915			143,215
Interest payable		63,173			112,659
Accrued expenses		614,094			418,290
Deferred revenues		-			32,479
Notes payable - current		764,278			764,278
Bonds payable – current portion		-			570,000
Creditors payable – current portion		300,000			186,761
Derivative liability – current portion		248,816			56,908
Total Current Liabilities		3,309,046			2,388,349

Non-Current Liabilities:
Asset retirement obligations		1,191,149			1,186,260
Deferred income tax liability		21,737			21,737
Line of credit		9,300,000			2,381,000
Derivative liability, net of current portion		258,675			28,086
Bonds payable, net of current portion		-			2,825,000
Creditors payable, net of current portion		1,052,783			1,352,783
Total Non-Current Liabilities		11,824,344			7,794,866

TOTAL LIABILITIES		15,133,390			10,183,215

STOCKHOLDERS’ EQUITY
Common stock , $0.001 par value, 36,363,637 shares authorized, 16,151,946 shares issued and outstanding at March 31, 2012 and December 31, 2011		16,152			16,152
Additional paid-in capital		32,617,689			32,617,690
Retained earnings (accumulated deficit)		(14,392,535	)		(15,050,680)
TOTAL STOCKHOLDERS’ EQUITY		18,241,306			17,583,162

TOTAL LIABILITIES AND STOCKHOLDERS’ EQUITY	$	33,374,696		$	27,766,377

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

Cross Border Resources, Inc.

Statements of Operations

For the three months ended March 31, 2012 and 2011

(Unaudited)


	2012			2011
REVENUES AND GAINS:
Oil and gas sales	$	3,573,746		$	1,566,813
Other		32,479			32,479
Total Revenues And Gains	$	3,606,225		$	1,599,292

OPERATING EXPENSES:
Operating costs		688,535			153,063
Production taxes		160,371			105,456
Depreciation, depletion, and amortization		661,469			584,290
Accretion expense		4,889			26,416
General and administrative		671,070			873,146
Total Operating Expenses		2,186,334			1,742,371

GAIN (LOSS) FROM OPERATIONS		1,419,891			(143,079	)

OTHER INCOME (EXPENSE):
Bond issuance amortization		(159,553	)		(4,664	)
Gain (loss) on derivatives		(473,913	)		30,266
Interest expense		(131,758	)		(105,156	)
Miscellaneous other income (expense)		3,478			42,019
Total Other Income (Expense)		(761,746	)		(37,535	)

GAIN (LOSS) BEFORE INCOME TAXES		658,145			(180,614	)

Current tax benefit (expense)		(222,869	)		30,868
Deferred tax benefit (expense)		222,869			(5,170	)
Income tax benefit (expense)		-			25,698

NET INCOME (LOSS)	$	658,145		$	(154,916	)

NET GAIN (LOSS) PER SHARE:
Basic and diluted	$	0.04		$	(0.01	)
WEIGHTED AVERAGE SHARES OUTSTANDING:
Basic and diluted		16,151,946			12,476,945

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

Cross Border Resources, Inc.

Statements of Cash Flows

For the Three Months Ended March 31, 2012 and 2011

(Unaudited)

	Three Months Ended March 31,
	2012			2011
CASH FLOWS FROM OPERATING ACTIVITIES
Net income (loss)	$	658,145		$	(154,916	)
Adjustments to reconcile net income (loss) to cash used by operating activities:
Depreciation, depletion, amortization		661,469			571,694
Accretion		4,889			26,416
Share-based compensation		-			30,492
Amortization of debt discount and deferred financing costs		218,631			17,260
Changes in operating assets and liabilities:
Accounts receivable		(1,721,387	)		(104,914	)
Prepaid expenses and other current assets		698,382			3,492,054
Accounts payable		1,022,225			(321,381	)
Derivative asset/liability		422,497			-
Accrued expenses		195,570			(201,175	)
Deferred income tax		-			(25,698	)
Deferred revenue		(32,479	)		(32,479	)
NET CASH PROVIDED BY (USED IN) OPERATING ACTIVITIES		2,127,942			3,297,353

CASH FLOWS FROM INVESTING ACTIVITIES
Cash impact of merger, net		-			(62,797	)
Capital expenditures - oil and gas properties		(5,867,736	)		(4,285,954	)
Capital expenditures - other assets		-			(45,146	)
NET CASH USED IN INVESTING ACTIVITIES		(5,867,736	)		(4,393,897	)

CASH FLOWS FROM FINANCING ACTIVITIES
Net borrowings (payments) on line of credit		6,919,000			1,212,500
Proceeds from renewing notes		-			128,037
Repayments of bonds		(3,395,000	)		(190,000	)
Repayments to creditors		(186,761	)		(266,760	)
NET CASH PROVIDED BY (USED IN) FINANCING ACTIVITIES		3,337,239			883,777

NET INCREASE (DECREASE) IN CASH AND CASH EQUIVALENTS		(402,555	)		(212,767	)
Cash and cash equivalents, beginning of period		472,967			975,123
Cash and cash equivalents, end of period	$	70,412		$	762,356

SUPPLEMENTAL DISCLOSURES OF CASH FLOW INFORMATION:
Interest paid	$	101,154		$	174,341
Income taxes paid	$	-		$	-

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

Cross Border Resources, Inc.

Notes to Unaudited Financial Statements

NOTE 1 – ORGANIZATION AND BUSINESS OPERATIONS

Nature of Operations

The Company is an independent natural gas and oil company engaged in the exploration, development, exploitation, and acquisition of natural gas and oil reserves in North America. The Company’s primary area of focus is the State of New Mexico, particularly southeastern New Mexico.

Reverse Acquisition

Effective December 27, 2010, the Company completed a 1-for-55 reverse split of its common stock in accordance with Article 78.207 of the Nevada Revised Statutes (the “Reverse Split”). The Reverse Split resulted in a decrease in the Company’s authorized share capital from 2,000,000,000 shares of common stock, par value $0.001 per share, to 36,363,637 shares of common stock, par value, $0.001 per share, with a corresponding decrease in the number of issued and outstanding shares of the Company’s common stock from 135,933,086 shares to 2,471,544 shares (after accounting for fractional share interests being rounded up to the next whole number). Completion of the Reverse Split was a condition precedent for the merger with Pure Gas Partners II, L.P. (“Pure”).

Effective January 3, 2011, the Company completed the acquisition of Pure Energy Group, Inc. (“Pure Sub”) as contemplated pursuant to the Agreement and Plan of Merger dated December 2, 2010 (the “Pure Merger Agreement”) among the Company, Doral Acquisition Corp., the Company’s wholly owned subsidiary (“Doral Sub”), Pure and Pure Sub, a wholly owned subsidiary of Pure (Pure Sub and Pure being collectively referred to herein as the “Pure Energy Group” or the "Predecessor").

Pursuant to the provisions of the Pure Merger Agreement, all of Pure’s oil and gas assets and liabilities were transferred to Pure Sub. Pure Sub was then merged with and into Doral Sub, with Doral Sub continuing as the surviving corporation (the “Pure Merger”). Upon completion of the Pure Merger, the outstanding shares of Pure Sub were converted into an aggregate of 9,981,536 shares of the Company’s common stock. As a result of the Pure Merger, the previous Pure shareholders owned approximately 80% of the Company’s total outstanding shares on a fully diluted basis, with the Company’s previous stockholders owning the remaining 20%, immediately following the merger.

The purchase price of the assets of the Company arising from the reverse acquisition with the Pure Energy Group was $8,085,984, representing eighty percent (80%) of the appraised value of 2,471,511 post-split shares of the Company which were issued and outstanding immediately prior to the reverse acquisition. The allocation of the purchase price and the purchase price accounting is based upon estimates of the assets and liabilities effectively acquired on January 3, 2011 in accordance with Financial Accounting Standards Board ("FASB") Accounting Standards Codification ("ASC") 805, Business Combinations.

NOTE 1 – ORGANIZATION AND BUSINESS OPERATIONS (continued)

The allocation of the purchase price is as follows:

Cash and cash equivalents	$	(62,798	)
Accounts receivable		94,810
Prepaid expenses and other current assets		5,769
Proved oil and gas properties		6,964,255
Property and equipment		12,643
Goodwill		1,395,807
Intangible assets		1,976,157
Other assets		228,268
Total assets		10,614,911
Accounts payable		(378,079	)
Accounts payable- related party		(69,917	)
Accrued liabilities		(182,110	)
Long-term debt		(1,018,322	)
Notes payable to related party		(250,000	)
Asset retirement obligation		(630,499	)
Purchase price	$	8,085,984

The statements of income include the results of operations for Cross Border Resources, Inc. commencing on January 4, 2011. As a result, information provided for the three months ended March 31, 2011 presented below includes the actual results of operations from January 4, 2011 to March 31, 2011 and the combined historical financial information for the Cross Border Resources, Inc. (formerly Doral Energy) and Pure for the period January 1, 2011 to January 3, 2011. The unaudited pro forma financial information for the three months ended March 31, 2011 presented below combines the historical financial information for the Cross Border Resources, Inc. and Pure for that period. The following unaudited pro forma information is not necessarily indicative of the results of future operations:

	Three Months Ended
	March 31,
	2012			2011
Revenues		$	3,606,225		$	1,599,292
Operating income (loss)			1,419,891			(154,309	)
Net income (loss)			658,145			(167,832	)

Earnings (loss) per share		$	0.04		$	(0.01	)

Basis for Presentation

The unaudited condensed balance sheet as of December 31, 2011 and the unaudited condensed statements of operations and cash flows for the three months ended March 31, 2011 include the accounts of the Predecessor for the period of January 1, 2011 to January 3, 2011 and the accounts of Pure and the Company for the period January 4, 2011 (date of reverse acquisition as discussed below) to March 31, 2011 (collectively, “Cross Border Resources, Inc.” or the “Company”). The comparative balance sheet as of March 31, 2012 and the unaudited condensed statements of operations and cash flows for the three month period ended March 31, 2012 represent the accounts of the Company. The business combination has been accounted for as a reverse acquisition wherein Pure is treated as the acquirer for accounting purposes.

In the opinion of management, all adjustments (consisting of normal recurring adjustments) considered necessary for a fair presentation have been included. Certain reclassifications have been made to the prior period to conform to current presentation.

NOTE 1 – ORGANIZATION AND BUSINESS OPERATIONS (continued)

Interim financial statements

The unaudited financial information furnished herein reflects all adjustments, which in the opinion of management are necessary to fairly state the Company’s financial position 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 financial statements and notes thereto included in the its Annual Report on Form 10-K for the year ended December 31, 2011, filed with the SEC on March 15, 2012. 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 its audited financial statements for the fiscal period ended December 31, 2011, may have been omitted. The results of operations for the three month periods ended March 31, 2012 are not necessarily indicative of results for the entire year ending December 31, 2012.

NOTE 2 – SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

Oil and Gas Properties

The Company uses the successful efforts method of accounting for oil and gas producing activities. Costs to acquire mineral interests in oil and gas properties, to drill and equip exploratory wells that find proved reserves, to drill and equip development wells and related asset retirement costs are capitalized. Costs to drill exploratory wells that do not find proved reserves, geological and geophysical costs, and costs of carrying and retaining unproved properties are expensed.

Unproved oil and gas properties that are individually significant are periodically assessed for impairment of value, and a loss is recognized at the time of impairment by providing an impairment allowance. Capitalized costs of producing oil and gas properties, after considering estimated residual salvage values, are depreciated and depleted by the unit-of-production method.

On the sale or retirement of a complete unit of a proved property, the cost, and related accumulated depreciation, depletion, and amortization are eliminated from the property accounts, and the resultant gain or loss is recognized. On the retirement or sale of a partial unit of proved property, the cost is charged to accumulated depreciation, depletion, and amortization with a resulting gain or loss recognized in income.

On the sale of an entire interest in an unproved property for cash or cash equivalent, gain or loss on the sale is recognized, taking into consideration the amount of any recorded impairment if the property had been assessed individually. If a partial interest in an unproved property is sold, the amount received is treated as a reduction of the cost of the interest retained.

Cash and Cash Equivalents

The Company considers all highly liquid investments with original maturities of three months or less to be cash equivalents.

Accounts Receivable - Production

Accounts receivable consist of amounts due from customers for oil and gas sales and are considered fully collectible by the Company as of March 31, 2012 and December 31, 2011. The Company determines when receivables are past due based on how recently payments have been received.

Revenue Recognition

The Company recognizes oil and natural gas revenue from its interests in producing wells when oil and natural gas is produced and sold from those wells.

NOTE 2 – SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (continued)

Property and Equipment

Property, plant, and equipment are stated at cost. Depreciation of office furniture and equipment is provided using the straight-line method and the Modified Accelerated Cost Recovery System (MACRS) based on estimated useful lives ranging from three to 15 years. These methods do not materially differ from generally accepted accounting principles. Depreciation expense was $7,935 and $9,479 for the three month periods ended March 31, 2012 and 2011, respectively.

Asset Retirement Obligations

The Company accounts for asset retirement obligations under the provisions of ASC 410, Asset Retirement and Environmental Obligations, which provides for an asset and liability approach to accounting for Asset Retirement Obligations (ARO). Under this method, when legal obligations for dismantlement and abandonment costs, excluding salvage values, are incurred, a liability is recorded at fair value and the carrying amount of the related oil and gas properties is increased. Accretion of liability is recognized each period using the interest method of allocation and the capitalized cost is depleted over the useful life of the related asset. Asset retirement obligations as of March 31, 2012 and December 31, 2011 were $1,191,149 and $1,186,260, respectively.

The following is a description of the changes to the Company’s asset retirement obligations for the year-to-date periods ended March 31, 2012 and December 31, 2011:

	2012		2011
Asset retirement obligations at beginning of year	$	1,186,260	$	508,588
Asset retirement obligations acquired in acquisition		-		630,499
Revision of previous estimates		-		(158,452	)
Accretion expense		4,889		84,428
Additions		-		121,197
Asset retirement obligations at end of period	$	1,191,149	$	1,186,260

Income Taxes

The Company is a taxable entity for federal or state income tax purposes for which an income tax provision has been made in the accompanying financial statements. Deferred income tax assets and liabilities are computed annually for differences between the financial statement and tax bases of assets and liabilities that will result in taxable or deductible amounts in the future based on enacted tax laws and rates applicable to the periods in which the differences are expected to affect taxable income. Valuation allowances are established when necessary to reduce deferred tax assets to the amount expected to be realized. Income tax expense is the tax payable or refundable for the period plus or minus the change during the period in deferred tax assets and liabilities. Differences between the enacted tax rates and the effective tax rates are primarily the result of timing differences in the recognition of depletion and accretion expenses. These differences do not create a material variance between the enacted tax rate and the effective tax rate. However, net tax expense has been reduced as the result of changes to the valuation allowance.

	Three Months Ended March 31,
	2012			2011
Amount computed at expected statutory rate (33.86% for 2012; 15% for 2011)		$	222,869		$	(23,237	)

Net income tax expense (benefit)		$	-		$	(25,698	)

Use of Estimates

The preparation of financial statements in conformity with generally accepted accounting principles requires management to make estimates and assumptions that affect the reported amounts of assets, liabilities, revenues, expenses and related disclosures. Actual results could differ from those estimates and assumptions. Significant estimates include volumes of oil and gas reserves used in calculating depletion of proved oil and natural gas properties and costs to abandon oil and gas properties.

NOTE 2 – SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (continued)

Management believes that it is reasonably possible the following material estimates affecting the financial statements could significantly change in the coming year: (1) estimates of proved oil and gas reserves, and (2) forecast forward price curves for natural gas and crude oil. The oil and gas industry in the United States has historically experienced substantial commodity price volatility, and such volatility is expected to continue in the future. Commodity prices affect the level of reserves that are considered commercially recoverable; significantly influence the Company’s current and future expected cash flows; and impact the PV10 derivation of proved reserves.

Financial Instruments

The Company’s financial instruments include cash and cash equivalents, receivables, payables, and debt and are accounted for under the provisions of ASC Topic 825, Financial Instruments. The carrying amount of these financial instruments as reflected in the balance sheets, except for long-term, fixed-rate debt, approximates fair value. The Company estimates the fair value of its long-term, fixed-rate debt generally using discounted cash flow analysis based on the Company's current borrowing rates for similar types of debt.

Comprehensive Income

The Company does not have any components of "other comprehensive income." Therefore Total Comprehensive Income (Loss) is not reported on the Statements of Operations.

Recently Issued Accounting Pronouncements

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

NOTE 3– STOCKHOLDERS' EQUITY AND EARNINGS PER SHARE

2011 Equity Financing

On May 26, 2011, the Company closed a private offering exempt from registration under the Securities Act of 1933 pursuant to Rule 506 of Regulation D promulgated thereunder. In the offering, the Company issued an aggregate of 3,600,000 units. Each unit was sold at $1.50 and was comprised of one share of common stock and one five-year warrant to purchase a share of common stock at an exercise price of $2.25 per share. The warrants became exercisable on November 26, 2011. The Company agreed to use the net proceeds from the sale of the units for general business and working capital purposes and not to use such proceeds for the redemption of any common stock or common stock equivalents.

The investors in the offering received registration rights. The Company agreed to file a registration statement covering the resale of the common stock issued and the common stock underlying the warrants issued to the Selling Stockholders within sixty days after the closing date. The registration statement was declared effective on August 5, 2011. If at the time of exercise of the warrants there is no effective registration statement covering the resale of the shares underlying the warrant, then the investors in the offering have the right at such time to exercise warrants in full or in part on a cashless basis.

In addition to registration rights, the investors in the offering were offered a right of first refusal to participate in future offerings of common stock if the principal purpose of which is to raise capital. This right of first refusal terminates upon the earlier of a sale, merger, consolidation or reorganization of the Company or May 26, 2012, the one-year anniversary of the closing date of the offering.

NOTE 3– STOCKHOLDERS' EQUITY AND EARNINGS PER SHARE (continued)

Warrants

In connection with the equity offering closed on May 26, 2011, the Company issued warrants to purchase an aggregate of 3,600,000 shares of the Company’s common stock at a per-share price of $2.25. The Company also has outstanding warrants to purchase 3,125 shares of the Company’s common stock at a per-share price of $5.00.

If all of these warrants are exercised for cash, the Company would receive $8,115,625 in aggregate proceeds. The warrants to purchase the 3,600,000 shares became exercisable in November 2011. The Company does not expect the immediate exercise of these warrants as the exercise price exceeds the average closing price. Furthermore, no assurances can be made that any of the warrants will ever be exercised for cash or at all.

Stock Options

In January 2011, the Company issued options to purchase a total of 1,602,500 shares of its common stock at option prices ranging from $4.80 to $6.38 per share. Of that total, 1,265,000 were issued to employees, 250,000 were issued to a consultant and 87,500 were issued to the Company's directors. During 2011, unvested options to purchase 325,000 shares were forfeited by an employee and a consultant whose relationship with the company ended and vested options to purchase 225,000 shares expired unused. During October 2011, the Company's board of directors offered to buy back all options held by current employees at $0.10 per option share. All employees accepted the offer, resulting in a total payment by the Company of $96,500.

At March 31, 2012, options to purchase 87,500 shares of stock at $4.80 per share remain outstanding, all of which are held by members of the Company's Board of Directors.

Earnings Per Share

The following table illustrates the calculation of earnings per share for the three month periods ended March 31:

	Three Month Periods
	2012		2011
Net income (loss)	$	658,145	$	(154,916	)
Weighted-average number of common shares		16,151,946		12,476,945
Earnings per common share:
Basic	$	0.04	$	(0.01	)
Diluted	$	0.04	$	(0.01	)

The exercise prices of all outstanding stock options and warrants, and the conversion price on convertible debt, exceeded the market price for the Company's common stock throughout the periods shown. Therefore there would have been no dilutive impact from these items for the periods. In periods where a net loss is incurred, any assumed exercise of stock options or warrants would be anti-dilutive.

NOTE 4– RELATED PARTY TRANSACTIONS

The Company paid $58,000 in consulting fees in the three month period ended March 31, 2011, to BDR Consulting, Inc. (BDR), a member of CCJ/BDR Investments, L.L.C., who owned a combined 64.108% limited partnership interest in the Pure Gas Partners II, L.P. The president of BDR also served on the Board of Directors and was the Chief Executive Officer of Pure Energy Group, Inc. BDR's services have not been used since the termination agreement in June 2011.

NOTE 5 – LONG TERM - DEBT

At March 31, 2012 and December 31, 2011, long-term debt consisted of the following items, excluding the operating line of credit:

	March 31,		December 31,
	2012		2011
7½% Debentures, Series 2005	$	-	$	3,395,000
Notes Payable – Greenshoe Investment		367,309		367,309
Notes Payable – Little Bay Consulting		396,969		396,969
Total Long-term Debt	$	764,278	$	4,159,278

7½% Debentures, Series 2005

On March 1, 2005, Pure Energy Group, Inc. and its subsidiary Pure Gas Partners, II, L.P., issued 7 ½ % Debentures, Series 2005, in the principal amount of $5,500,000 (the “Pure Debentures”. The Pure Debentures were secured by all revenues of the issuer and all money held in the funds and accounts created under the Indenture. The Pure Debentures would have matured on March 1, 2015, if not redeemed, with principal and interest payable semi-annually on March 1 and September 1. As of March 31, 2012 and December 31, 2011, the balance payable was $0 and $3,395,000, respectively. Interest expense related to the Pure Debentures for the three months ended March 31, 2012 and 2011 was $43,708 and $79,942, respectively.

As permitted by the bond debt agreement, the Company purchased bonds back on the open market at its discretion. Pure Debentures held by the Company at March 31, 2012 and December 31, 2011 totaled $0 and $100,000, respectively. These Pure Debentures were purchased at a discount of $16,719 during 2011. The Pure Debentures held by the Company are shown as a reduction of bonds payable on the balance sheet as follows:

	March 31,		December 31,
	2012		2011
Bonds Payable	$	-	$	3,395,000
Less: Bonds held by the Company		-		(100,000	)
Total	$	-	$	3,295,000

Redemption of Pure Debentures: On January 31, 2012, the Company called for payment prior to maturity all of the Pure Debentures. The redemption of 100% of the Pure Debentures was completed on March 1, 2012.

NOTE 5 – LONG TERM - DEBT (continued)

Notes Payable Green Shoe Investments

In connection with the merger, the Company, as the accounting acquirer, assumed an unsecured loan from Green Shoe Investments Ltd. (“Green Shoe”) in the principal amount of $487,000 at an interest rate of 5.0%

On April 26, 2011, the Company entered into a Loan Agreement with Green Shoe, and the Company executed and delivered a Promissory Note to Green Shoe in connection therewith. The amount of the Promissory Note and the loan from Green Shoe (the “Green Shoe Loan”) is $550,936 and the purpose of the Green Shoe Loan is to consolidate and extend all of the loans owed by the Company and its predecessors to Green Shoe including without limitation the following: (i) loan dated May 9, 2008 in the principal amount of $100,000, (ii) loan dated May 23, 2008 in the principal amount of $150,000, (iii) loan dated July 18, 2008 in the principal amount of $50,000, (iv) loan dated February 24, 2009 in the principal amount of $100,000, and (v) loan dated April 29, 2009 in the principal amount of $87,000 plus accrued interest of $63,936. The Green Shoe Loan is unsecured.

Beginning March 31, 2011 (the effective date of the Promissory Note), the amounts owed under the Promissory Note began to accrue interest at a rate of 9.99%, and the Promissory Note provides that no payments of principal or interest are due until the maturity date of September 30, 2012. The Company is obligated to pay all accrued interest and make a principal payment equal to one-third of the principal owed upon the closing of an equity offering resulting in a specified amount of net proceeds to the Company. In addition, Green Shoe was granted the right to convert the principal and interest owed into shares of common stock of the Company at a conversion price of $4.00 per share. The principal balance of these amounts as of March 31, 2012 and December 31, 2011 was $367,309, which is shown in Current Liabilities on the Balance Sheet.

Notes Payable Little Bay Consulting

In connection with the merger, the Company, as the accounting acquirer, assumed an unsecured loan from Little Bay Consulting SA (“Little Bay”) in the principal amount of $520,000 at an interest rate of 5%.

On April 26, 2011, the Company entered into a Loan Agreement with Little Bay, and the Company executed and delivered a Promissory Note to Little Bay in connection therewith. The amount of the Promissory Note and the loan from Little Bay (the “Little Bay Loan”) is $595,423 and the purpose of the Little Bay Loan is to consolidate and extend all of the loans owed by the Company and its predecessors to Little Bay including without limitation the following: (i) loan dated March 7, 2008 in the original principal amount of $220,000, (ii) loan dated July 18, 2008 in the original principal amount of $100,000, and (iii) loan dated October 3, 2008 in the principal amount of $200,000 plus accrued interest of $75,423. The Little Bay Loan is unsecured.

Beginning March 31, 2011 (the effective date of the Promissory Note), the amounts owed under the Promissory Note began to accrue interest at a rate of 9.99%, and the Promissory Note provides that no payments of principal or interest are due until the maturity date of September 30, 2012. The Company is obligated to pay all accrued interest and make a principal payment equal to one-third of the principal owed upon the closing of an equity offering resulting in a specified amount of net proceeds to the Company. In addition, Little Bay was granted the right to convert the principal and interest owed into shares of common stock of the Company at a conversion price of $4.00 per share. The principal balance of these borrowings as of March 31, 2012 and December 31, 2011 was $396,969, which is shown in Current Liabilities on the Balance Sheet.

NOTE 6 – OPERATING LINE OF CREDIT

As of December 31, 2011, the borrowing base on the line of credit was $4,500,000. Effective March 1, 2012, the borrowing base was increased to $9,500,000. The interest rate was calculated at the greater of the adjusted base rate or 4% . The line of credit is collateralized by producing wells and matures on January 14, 2014. As of March 31, 2012 and December 31, 2011, the outstanding balance on the line of credit was $9,300,000 and $2,381,000, respectively. Interest expense for the three months ended March 31, 2012 and 2011 was $55,630 and $25,215, respectively. The line of credit is reported as long-term debt because the maturity date is greater than one year. During April 2012, the Company drew down a total of $200,000 on this facility, leaving no unused balance.

NOTE 7 – CREDITORS PAYABLE

In 2002, the prior owner of Pure Sub filed a petition for reorganization with the United States Bankruptcy Court. According to the plan of reorganization, three creditors were to receive a combined amount of approximately $3,000,000 for their claims out of future net revenues of Pure Sub (defined as revenues from producing wells net of lease operating expenses and other direct costs).

The net estimated revenue distribution due to creditors in 2013 based on expected 2012 net revenues is $300,000, which is presented as a current liability. The related distribution based on 2011 net revenues was $186,761 as of December 31, 2011, which had been reduced for an over payment in the prior year and was paid in February 2012. As of March 31, 2012 and March 31, 2011, the combined creditors’ payable balances were $1,352,783 and $1,539,545, respectively.

NOTE 8 – OPERATING LEASES

The Company has a non-cancelable operating lease for office space expiring in June 2014. As of December 31, 2011, the remaining future minimum lease payments under the existing lease are as follows:

Year Ending December 31,	Operating Lease
2012	$	50,000
2013		51,250
2014		26,250
2015		-
2016		-
Total Minimum Lease Payments	$	127,500

Rent expense related to leases for the three month periods ended March 31, 2012 and 2011 was $13,720 and $11,875, respectively.

NOTE 9 – COMMITMENTS AND CONTINGENCIES

The Company is subject to federal and state laws and regulations relating to the protection of the environment. Environmental risk is inherent to oil and natural gas operations and the Company could be subject to environmental cleanup and enforcement actions. The Company manages this environmental risk through appropriate environmental policies and practices to minimize the impact to the Company.

From time to time, the Company is a party to various legal proceedings arising in the ordinary course of business. The Company is not currently a party to any proceeding that it believes could have a material adverse effect on the Company’s financial condition, results of operation or cash flows.

The changes resulting from the Settlement Agreement signed on April 23, 2012 (see Note 13) triggered the change in control provisions under existing agreements with employees. A total of approximately $1.0 million is payable to employees in four installments over the remainder of 2012. The costs will be reflected in general and administrative expenses in the Statement of Operations in the period they were triggered (May 2012). Approximately 50% will be paid in the second quarter of 2012 and 25% each in the third and fourth quarters of 2012. Details of the payment calculation were disclosed in the Company's Form 10-K for the year ended December 31, 2011, filed with the SEC on March 15, 2012.

NOTE 10 – CONCENTRATIONS OF CREDIT RISK

Financial instruments that potentially subject the Company to the concentration of credit risk consist primarily of cash and cash equivalents. Cash balances did not exceed FDIC normal insurance protection levels at March 31, 2012 and 2011. However, Section 343 of the Dodd-Frank Wall Street Reform and Consumer Protection Act (“DFA”) provides temporary unlimited deposit insurance coverage for noninterest-bearing transaction accounts at all FDIC-insured depository institutions.

The Company also maintains cash balances with two investment brokerage firms that are protected by the Securities Investor Protection Corporation (SIPC) up to $250,000. In addition to the SIPC coverage, one of the investment brokerage firms provides supplemental coverage in excess of SIPC through an insurance policy that covers cash balances up to $500,000. The cash balance at the other investment brokerage firm is held in a FDIC-Insured Deposit Account and is also protected by a supplemental coverage insurance policy that covers cash balances up to $124,500,000. As of March 31, 2012 and 2011, the Company’s cash balance with these investment brokerage firms did not exceed the combined coverage.

NOTE 11 – DERIVATIVE INSTRUMENTS AND PRICE RISK MANAGEMENT ACTIVITIES

ASC 815-25 (formerly SFAS No. 133 “Accounting for Derivative Instruments and Hedging Activities”) requires that all derivative instruments be recorded on the balance sheet at their fair value. Changes in the fair value of each derivative are recorded each period in current earnings or other comprehensive income, depending on whether the derivative is designated as part of a hedge transaction and, if it is, the type of hedge transaction. When choosing to designate a derivative as a hedge, management formally documents the hedging relationship and its risk-management objective and strategy for undertaking the hedge, the hedging instrument, the item, the nature of the risk being hedged, how the hedging instrument’s effectiveness in offsetting the hedged risk will be assessed, and a description of the method of measuring effectiveness. This process includes linking all derivatives that are designated as cash-flow hedges to specific cash flows associated with assets and liabilities on the balance sheet or to specific forecasted transactions. Based on the above, management has determined the swaps noted below do not qualify for hedge accounting treatment.

At March 31, 2012, we had a net derivative liability of $507,491, up from $84,994 at the prior year end. The change in net derivative liability of $422,497 is expensed as non-cash mark-to-market expense. Net realized hedge settlement losses for the three months ended March 31, 2012 and 2011 totaled $51,416, and $0, respectively. The combination of these two components of derivative expense/income is reflected in "Other Income (Expense)" on the Statements of Operations as "Gain (loss) on derivatives."

As of March 31, 2012, we have crude oil swaps in place relating to a total of 4,000 Bbls per month, as follows:

				Price		Volumes		Fair Value of Outstanding Derivative Contracts (1) (in thousands) as of
Transaction				Per		Per		March 31,			December 31,
Date	Type (2)	Beginning	Ending	Unit		Month		2012			2011
March 2011	Swap	04/01/2011	02/28/2013	$	104.55		1,000	$	(1,487	)	$	83,594
November 2011	Swap	12/01/2011	11/30/2014	$	93.50		2,000		(568,244	)		(168,588	)
February 2012	Swap	03/01/2012	02/28/2014	$	106.50		1,000		62,240
								$	(507,491	)	$	(84,994	)

(1) The fair value of the Company's outstanding transactions is presented on the balance sheet by counterparty. Currently all of our derivatives are with the same counterparty. The balance is shown as current or long-term based on our estimate of the amounts that will be due in the relevant time periods at currently predicted price levels. Amounts in parentheses indicate liabilities.

(2) These crude oil hedges were entered into on a per barrel delivered price basis, using the NYMEX - West Texas Intermediate Index, with settlement for each calendar month occurring following the expiration date, as determined by the contracts.

NOTE 12 – FAIR VALUE MEASUREMENTS

Cross Border Resources, Inc. commodity derivatives are measured at fair value in the financial statements. The Company’s financial assets and liabilities are measured using input from three levels of the fair value hierarchy. A financial asset or liability classification within the hierarchy is determined based on the lowest level input that is significant to the fair value measurement. The three levels are as follows:

Level 1 –

Inputs are unadjusted quoted prices in active markets for identical assets or liabilities that Cross Border Resources, Inc. has the ability to access at the measurement date.

Level 2 –

Inputs include quoted prices for similar assets and liabilities in active markets, quoted prices for identical or similar assets or liabilities in markets that are not active, inputs other than quoted prices that are observable for the asset or liability and inputs that are derived principally from or corroborated by observable market data by correlation or other means (market corroborated inputs).

Level 3 –

Unobservable inputs reflect Cross Border Resources, Inc’s judgments about the assumptions market participants would use in pricing the asset or liability since limited market data exists. The Company develops these inputs based on the best information available, using internal and external data.

The following table presents the Company’s assets and liabilities recognized in the balance sheet and measured at fair value on a recurring basis as of March 31, 2012:

	Input Levels for Fair Value Measurements
Description	Level 1		Level 2			Level 3		Total
Current Assets / (Liabilities):
Commodity derivatives, current portion	$	—	$	(248,816	)	$	—	$	(248,816	)
Other Assets / (Liabilities):
Commodity derivatives, long-term				(258,675	)				(258,675	)
	$	—	$	(507,491	)	$	—	$	(507,491	)

The fair value of derivative assets is determined using forward price curves derived from market price quotations, externally developed models, with internal and external fundamental data inputs. Market price quotations are obtained from independent energy brokers and direct communication with market participants.

NOTE 13 – SUBSEQUENT EVENTS

On April 23, 2012, the Company entered into an agreement (“Settlement Agreement”) with Red Mountain Resources, Inc. (“Red Mountain”). Pursuant to the Settlement Agreement and effective on May 8, 2012, Red Mountain's lawsuit against the Company and the Company's directors filed with the District Court for Clark County, Nevada (the “Action”) was dismissed with prejudice. Additionally and also effective on May 8, 2012, Everett Willard Gray, II, Lawrence J. Risley and Brad E. Heidelberg resigned from the Board of Directors of the Company (with Richard F. LaRoche, Jr. and John W. Hawkins remaining as members of the Board) and Alan W. Barksdale, Randell K. Ford and Paul N. Vassilakos, each a member of Red Mountain’s board of directors, were appointed as directors of the Company to fill the vacancies. Messrs. Ford, Vassilakos, LaRoche and Hawkins are expected to be independent directors.

NOTE 13 – SUBSEQUENT EVENTS (continued)

The Settlement Agreement contains the following terms in order to provide certain protections to the stockholders of the Company:

· The newly-constituted Board of the Company will not cause a merger, sale, or exchange of assets between the Company and Red Mountain prior to December 31, 2012. This period may be reduced at any time if approved by a majority of the Company’s independent directors or two-thirds of its stockholders, and deemed appropriate for the Company’s stockholders via an independent fairness opinion that the transaction is fair to unaffiliated stockholders of the Company.

· Everett Willard Gray II, Chairman and CEO, and Larry Risley, President and Chief Operating Officer, will resign as officers of the Company with such resignations to be effective on May 31, 2012. It is anticipated that the newly-constituted Board will appoint a new Chief Executive Officer simultaneous with the effectiveness of these resignations. However, the parties have agreed that the new executives will receive no more compensation than the former executives would have received in aggregate over the period ending December 31, 2012.

· To avoid potential conflicts of interest, the newly-constituted Board will not appoint any person who currently serves as an officer or director of Red Mountain or its affiliates to serve as an executive officer of the Company.

· The newly-constituted Board will cause the Company to hold an annual meeting for the election of directors as soon as practicable but no later than September 30, 2012.

The Company’s stockholders have been named as third party beneficiaries of the Settlement Agreement so that they may cause the newly-constituted Board to comply with these terms.

ITEM 2. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS

FORWARD-LOOKING STATEMENTS

Certain statements contained in this Quarterly Report on Form 10-Q constitute “forward-looking statements.” These statements, identified by words such as “plan,” “anticipate,” “believe,” “estimate,” “should,” “expect” and similar expressions include our expectations and objectives regarding our future financial position, operating results and business strategy. These statements reflect the current views of management with respect to future events and are subject to risks, uncertainties and other factors that may cause our actual results, performance or achievements, or industry results, to be materially different from those described in the forward-looking statements. Such risks and uncertainties include those set forth under the caption “Part II – Item 1A. Risk Factors” and elsewhere in this Quarterly Report. We do not intend to update the forward-looking information to reflect actual results or changes in the factors affecting such forward-looking information. We advise you to carefully review the reports and documents, particularly our Annual Reports, our Quarterly Reports and our Current Reports we file from time to time with the United States Securities and Exchange Commission (the “SEC”). Copies of all of our filings with the SEC may be accessed by visiting the SEC site (http://www.sec.gov) and performing a search of our electronic filings.

BUSINESS OVERVIEW

General Overview

Cross Border Resources, Inc. is an oil and gas exploration company resulting from the business combination of Doral Energy Corp. and Pure Gas Partners II, L.P. ("Pure L.P."), effective January 3, 2011. We own over 868,000 gross (approximately 295,000 net) mineral and lease acres in New Mexico and Texas. Approximately 26,000 of these net acres exist within the Permian Basin. A significant majority of our acreage consists of either owned mineral rights or leases held by production, allowing us to hold lease rental payments to under $5,000 annually. The remainder of our acreage interests consists of operated and non-operated working interests.

Current development of our acreage is focused on our prospective Bone Spring acreage located in the heart of the 1st and 2nd Bone Spring play. This play encompasses approximately 4,390 square miles across both New Mexico and Texas. We currently own varying, non-operated working interests in both Eddy and Lea Counties, New Mexico, along with our working interest partners that include Cimarex, Apache, and Mewbourne, all having significant footprints within this play.

Successful 2nd Bone Spring completions during 2011 and continuing into the first quarter of 2012 have been instrumental in increasing our net daily production from 271 barrels of oil equivalent per day (“boepd”) at January 3, 2011 to a net daily production rate of approximately 750 boepd for March 2012. This represents a 177% production increase in a 15-month period.

Additional development is currently underway on our Abo, Yeso, and Wolfberry acreage with our other working interest partners, Concho Resources, Big Star and Oxy. We currently have a drilling inventory across these formations with varying non-operated working interests ranging from 1.05% to 20%.

During the first three months of 2012, we participated in seven gross (1 net) new wells. As of April 30, 2012, three of the seven new wells had been placed on production, while four are awaiting completion. Additionally, three of the four wells that began during 2011 and were awaiting completion at year end 2011 were successfully completed during the first quarter of 2012. No new leasehold acquisitions were made during first quarter 2012.

SETTLEMENT AGREEMENT

On April 23, 2012, the Company entered into an agreement (“Settlement Agreement”) with Red Mountain Resources, Inc. (“Red Mountain”) to settle litigation filed by Red Mountain against the Company as further described in Item 1 of Part II of this report. Pursuant to the Settlement Agreement and effective on May 8, 2012, the litigation was dismissed and Everett Willard Gray, II, Lawrence J. Risley and Brad E. Heidelberg resigned from the Board of Directors of the Company (with Richard F. LaRoche, Jr. and John W. Hawkins remaining as members of the Board) and Alan W. Barksdale, Randell K. Ford and Paul N. Vassilakos, each a member of Red Mountain’s board of directors, were appointed as directors of the Company to fill the vacancies. Messrs. Ford, Vassilakos, LaRoche and Hawkins are expected to be independent directors.

The Settlement Agreement also contains certain terms in order to provide certain protections to the stockholders of the Company. See Note 13 "Subsequent Events" for a listing of these terms. For more information on the Settlement Agreement, please see the Information Statement (Schedule 14F-1) filed by the Company with the SEC on April 27, 2012.

STRATEGIC ALTERNATIVES

In February 2012, we announced that our Board of Directors had decided to engage in a broad review of strategic alternatives aimed at maximizing shareholder value. The purpose of the strategic review was to evaluate the Company's current long-term business plan against a range of alternatives that have the potential to maximize shareholder value including strategic financing opportunities, asset divestitures, joint ventures and/or a corporate sale, merger or other business combination. The Company engaged KeyBanc Capital Markets as its financial advisor to assist the Company with its evaluation of strategic opportunities. The strategic review process was not initiated as a result of any particular offer. Activity under this review has been delayed until the new Board is seated as a result of the Settlement Agreement.

RESULTS OF OPERATION

Summary of Production

The following summarizes our net production sold for the three month periods ended March 31:

	2012		2011		% Change
Oil (Bbls)		32,415		13,287		144	%
Gas (mcf)		54,370		50,911		7	%
Total barrels of oil equivalent (boe)*		41,477		21,772		91	%
Average barrels of oil equivalent per day (“boepd”)		456		242		88	%

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

This increase in oil and gas sales volumes is due primarily to increased production from wells added period over period. The 2012 Quarter had one additional production day when comparing to the 2011 Quarter. During the month of March 2012, production averaged 751 boepd primarily due to the Cimarex SE Lusk 2H and 3H wells coming on production.

Set forth in the following schedule is the average sales price per unit and average cost of production produced by us for the three month periods ended March 31:

	Three Months Periods
	2012		2011		% Change
Average sales price:
Oil ($ per bbl)	$	98.46	$	89.19		10	%
Gas ($ per mcf)	$	5.86	$	6.22		(6	)%
Average cost of production:
Average production cost ($/boe)	$	15.62	$	7.25		115	%
Average production taxes ($/boe)	$	3.86	$	5.45		(29	)%

Three months ended March 31, 2012 and 2011

Summary of First Quarter Results

	Three Months Ended March 31						Percentage Increase /
	2012			2011			(Decrease)
Revenue and Gains	$	3,606,225		$	1,599,292			125	%
Operating Expenses		(2,186,334	)		(1,742,371	)		25	%
Other Income (Expense)		(761,746	)		(37,535	)		1,929	%
Income Tax (Expense) Benefit		-			25,698			n/m
Net Income (Loss)	$	658,145		$	(154,916)			n/m

n/m - When moving from income to expense, or from expense to income, the percentage change is not meaningful.

Revenues

We recognized $3.6 million in revenues from sales of oil and natural gas for the three months ended March 31, 2012 (the “2012 Quarter”), compared to $1.6 million for the three months ended March 31, 2011 (the “2011 Quarter”.) This 128% increase in oil and gas sales revenue is due primarily to increased production from wells added period over period. Sales volumes on a boe basis were up approximately 91% for the 2012 Quarter over the 2011 Quarter. In addition, average prices for crude oil sold period over period increased by 10%. We report our revenues on wells in which we have a working interest based on information received from operators. The recognition of revenues in this manner is in accordance with generally accepted accounting principles.

We also recognized deferred revenue of $32,479 during both the 2011 and 2012 Quarters. The deferred revenues have now been fully recognized and, therefore, will not be continued in future periods.

Operating Expenses

Our operating expenses for the 2012 Quarter and 2011 Quarter consisted of the following:

	Three Months Ended March 31,				Percentage Increase /
	2012		2011		(Decrease)
Operating Costs	$	688,535	$	153,063		350	%
Production Taxes		160,371		105,456		52	%
Depreciation, Depletion, and Amortization		661,469		584,290		13	%
Accretion Expense		4,889		26,416		(81	)%
General and Administrative		671,070		873,146		(23	)%
Total	$	2,186,334	$	1,742,371		25	%

Operating costs were higher as a result of costs related to additional wells brought on line year over year. Production taxes and depletion were higher as a result of higher production on wells recently placed on production. General and administrative expense ("G&A") decreased primarily as a result of lower costs for professional services and no stock compensation expense during the 2012 Quarter. This decrease is somewhat offset by the inclusion of a $65,000 accrual for employee bonuses during the 2012 Quarter, while during 2011 no employee bonuses were accrued until the fourth quarter of the year.

G&A as a percentage of "Revenue and Gains" was reduced to 19% for the 2012 Quarter from 55% during the 2011 Quarter, primarily as a result of higher oil and gas revenue. The 'Non-recurring Expenses' discussed below are included in, and not in addition to, G&A on the Statements of Operations.

Non-recurring Expenses

G&A in the 2011 Quarter included about $255,000 in non-recurring expenses (legal, accounting, professional and transaction related fees and expenses) related to the Pure merger.

In the 2012 Quarter, the Company incurred approximately $100,000 in G&A related to defense against a lawsuit and proxy contest with a significant shareholder. While both of these were settled during the second quarter of 2012, we estimate additional related costs of about $100,000 will be expensed during the second quarter of 2012.

Additionally, during the second quarter of 2012 we anticipate an accrued expense of approximately $1.0 million related to change in control payments triggered by the change in the composition of the board of directors that occurred on May 8, 2012. The payments are scheduled to be made in four installments over the remainder of 2012.

We also anticipate filing an amendment to our registration statement during the second quarter of 2012 as a result of the change in control. Attorney and filing fees related to this process have not yet been estimated.

As a result of these pending expenses, we expect that our G&A as a percentage of revenue to be near its 2011 Quarter level for the second quarter of 2012 and to decline again in the third quarter of 2012.

Price Risk Management Activities

During the 2012 Quarter, we recognized a loss of $473,913, which includes $51,416 of realized hedge settlements paid for the difference between the hedged price and the market price in closed months, as well as a $422,497 non-cash mark to market loss on the remaining term of our crude oil fixed price swaps. This compares with a $30,266 non-cash mark to market gain recognized during the 2011 Quarter. Our crude oil fixed price swaps currently cover a total of 4,000 barrels of oil per month. See the table in Note 11 for more information on these swaps.

Non-GAAP Financial Measures

Adjusted EBITDA

In addition to reporting net earnings (loss) as defined under GAAP, we also present net earnings before interest, income taxes, depreciation, depletion, and amortization (adjusted EBITDA), which is a non-GAAP performance measure. Adjusted EBITDA consists of net earnings after adjustment for those items described in the table below. Adjusted EBITDA does not represent, and should not be considered an alternative to GAAP measurements, such as net earnings (loss) (its most comparable GAAP financial measure), and our calculations thereof may not be comparable to similarly titled measures reported by other companies. By eliminating the items described below, we believe the measure is useful in evaluating its fundamental core operating performance. We also believe that adjusted EBITDA is useful to investors because similar measures are frequently used by securities analysts, investors, and other interested parties in their evaluation of companies in similar industries. Our management uses adjusted EBITDA to manage our business, including in preparing its annual operating budget and financial projections. Our management does not view adjusted EBITDA in isolation and also uses other measurements, such as net earnings (loss) and revenues to measure operating performance. The following table provides a reconciliation of net earnings (loss), the most directly comparable GAAP measure, to adjusted EBITDA for the periods presented:

	Three Months Ended
	March 31
	2012		2011
Net income (loss)	$	658,145	$	(154,916	)
Interest expense		131,758		105,156
Loan fee amortization		159,553		4,664
Income tax expense (benefit)		-		(25,698	)
Accretion of asset retirement obligations		4,889		26,416
Depreciation, depletion, and amortization		661,469		584,290
Stock-based compensation		-		30,492
Mark-to-market loss (gain) on commodity swaps		422,497		(30,267	)
Adjusted EBITDA	$	2,038,311	$	540,137

Both Net Income and Adjusted EBITDA are expected to decline significantly for the second quarter of 2012 as a result of the pending expenses discussed under "Non-recurring Expenses" on the previous page.

LIQUIDITY AND CAPITAL RESOURCES

Liquidity is a measure of ability to access cash. Our primary needs for cash are for exploration, exploitation, development and acquisition of oil and gas properties, repayment of contractual obligations and working capital funding. We have historically addressed our long-term liquidity requirements through cash provided by operating activities, by the issuance of debt and equity securities when market conditions permit, through the sale of non-strategic assets, and through our credit facilities. The prices for future oil and natural gas production and the level of production have significant impacts on operating cash flows and cannot be predicted with any degree of certainty. We continue to examine alternative sources of long-term capital, including bank borrowings, the issuance of debt instruments, the sale of equity securities, the sales of strategic and non-strategic assets, and joint-venture financing. Availability of these sources of capital and, therefore, our ability to execute our operating strategy will depend upon a number of factors, some of which are beyond our control.

Redemption of Debentures

On March 1, 2012, we used approximately $3.3 million in the redemption of the remaining 7 ½ % Debentures, Series 2005 (the “Pure Debentures”) issued by Pure Energy Group in March 2005, that had been assumed in the Pure Merger. The redemption of the Pure Debentures eliminated a covenant that limited the Company's senior debt to no more than $5.0 million and allowed the borrowing base on our line of credit to increase in proportion to our increased proved reserves.

Change in Control Liability

The Company will be required to pay approximately $0.5 million to employees during the second quarter of 2012, as the result of the triggering of certain change in control provisions in agreements with employees. The remaining payments, also totaling approximately $0.5 million, will be due in two equal installments in September and December of 2012.

Working Capital

At March 31, 2012 our working capital was $750,427, as compared to $1,099,843 at December 31, 2011.

	At March 31, 2012		At December 31, 2011		Percentage Increase / (Decrease)
Current Assets	$	4,059,473	$	3,488,192		16	%
Current Liabilities		3,309,046		2,388,349		39	%
Working Capital	$	750,427	$	1,099,843		(32)	%
Working Capital Ratio		1.23		1.46		(16)	%

Cash Flows

	Three Months Ended
	March 31
	2012			2011
Cash Flows Provided by Operating Activities	$	2,127,942		$	3,297,353
Cash Flows Used in Investing Activities		(5,867,736	)		(4,393,897	)
Cash Flows Provided by (Used in) Financing Activities		3,337,239			883,777
Net Increase (Decrease) in Cash During Period	$	(402,555	)	$	(212,767	)

Cash used in operating activities is calculated by starting with the net income or loss for the period and adjusting for the non-cash income and expense items during the period, as well as for the change in operating assets and liabilities. As an example: During the 2011 Quarter our Total Current Liabilities balance increased to $3.3 million from $2.4 million. This increase in liabilities, due primarily to increased activity levels, is reflected as a provision of cash from operating activities, but reduces the current ratio. Conversely, the increase in accounts receivable, due to higher crude oil sales, is a decrease to cash provided from operating activities.

Cash used in investing activities represents capital expenditures for the drilling of wells. The increase in this measure is a reflection of the increased level of drilling and completion activity for wells on our acreage.

Cash provided by financing activities represents funds from new borrowings under our line of credit, reduced by funds used to redeem the Pure Debentures in full and repayment of indebtedness to creditors.

Amended and Restated Credit Agreement with Texas Capital Bank

On January 31, 2011, we entered into an amended and restated credit agreement (the “Credit Agreement”) with Texas Capital Bank, N.A. (“TCB”). The Credit Agreement provided the Company with an initial borrowing base of $4 million. Increases to the initial borrowing base were received on December 20, 2011 (to $4.5 million) and on March 1, 2012 (to $9.5 million). The amount available under the Credit Agreement may be increased by TCB up to $25.0 based on the Company’s reserve reports and the value of the Company’s oil and gas properties. Prior to the redemption of the Pure Debentures, effective March 1, 2012, the Indenture for the Pure Debentures limited the Company's borrowing amount to $5,000,000. As of March 31, 2012, the Company had available to it $0.2 million under the Credit Agreement. During April 2012, we drew down the remaining available balance. The Company has no other credit facilities or source of cash, other than operating revenues. The Credit Agreement is described more fully in and is attached as an exhibit to the Company’s Form 8-K dated February 7, 2011 and the amendment thereto is described more fully and is attached as an exhibit to the Company's Form 8-K dated March 1, 2012.

CONTRACTUAL OBLIGATIONS

Little Bay and Green Shoe

At March 31, 2012, we are indebted to Little Bay Consulting SA (“Little Bay”) and Green Shoe Investments Ltd. (“Green Shoe”) in the principal amounts of $396,969 and $367,309 respectively for loans refinanced in fiscal 2011, with a combined accrued interest balance of $63,173. Those loans are due in full, with accrued interest at September 30, 2012, with no periodic payments until maturity (other than upon an equity raise resulting in net proceeds of more than $1,000,000), as described more fully in the Company’s 8-K filed April 28, 2011.

OFF-BALANCE SHEET ARRANGEMENTS

We have no significant off-balance sheet arrangements that have or are reasonably likely to have a current or future effect on our financial condition, changes in financial condition, revenue or expenses, results of operations, liquidity, capital expenditures or capital resources that is material to our stockholders.

However, the changes resulting from the Settlement Agreement signed on April 23, 2012 triggered the change in control provisions under existing agreements with employees. A total of approximately $1.0 million is payable to employees in four installments over the remainder of 2012. The costs will be reflected in G&A in the Statement of Operations in the period in which they were triggered (April 2012). Approximately 50% will be paid in the second quarter of 2012 and 25% each in the third and fourth quarters of 2012. Details of the payment calculation were disclosed in the Company's Form 10-K for the year ended December 31, 2011, filed with the SEC on March 15, 2012.

CRITICAL ACCOUNTING POLICIES

The preparation of financial statements in conformity with generally accepted accounting principles ("GAAP") in the United States has required our management to make assumptions, estimates and judgments that affect the amounts reported in the financial statements, including the notes thereto, and related disclosures of commitments and contingencies, if any. Our significant accounting policies are disclosed in the notes to the interim financial statements for the period ended March 31, 2012 included in this Quarterly Report on Form 10-Q.

The financial statements presented with this Quarterly Report on Form 10-Q have been prepared in accordance with generally accepted accounting principles in the United States of America for interim financial information. These financial statements do not include all information and footnote disclosures required for an annual set of financial statements prepared under United States generally accepted accounting principles. In the opinion of our management, all adjustments (consisting solely of normal recurring accruals) considered necessary for a fair presentation of the financial position, results of operations and cash flows for all periods presented in the attached financial statements, have been included. Interim results for the period ended March 31, 2012 are not necessarily indicative of the results that may be expected for the fiscal year as a whole.

Our significant accounting policies are disclosed at Note 2 to the unaudited financial statements included with this Quarterly Report.

ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURE ABOUT MARKET RISK

The Company qualifies as a smaller reporting company and is not required to provide this information.

ITEM 4. CONTROLS AND PROCEDURES

Disclosure Controls and Procedures

Disclosure controls and procedures include, without limitation, controls and procedures designed to ensure that information required to be disclosed by an issuer in the reports that it files or submits under the Securities Exchange Act of 1934, as amended (the “Exchange Act”) is accumulated and communicated to the issuer's management, including its principal executive and principal financial officers as appropriate to allow timely decisions regarding required disclosure. It should be noted that the design of any system of controls is 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, regardless of how remote.

Under the supervision and with the participation of our management, including our Chief Executive Officer, President and Chief Accounting Officer, we have evaluated the effectiveness of our disclosure controls and procedures as required by Exchange Act Rule 13a-15(b) as of the end of the period covered by this report. Based on that evaluation, our Chief Executive Officer, President and Chief Accounting Officer have concluded that our disclosure controls and procedures were effective as of the end of the period covered by this Quarterly Report in ensuring that the information required to be disclosed by us in the reports that we file or submit under the Exchange Act were reported within the time periods specified in the SEC’s rules and forms.

Changes in Internal Control over Financial Reporting

There were no changes in our internal control over financial reporting during our most recent fiscal quarter that materially affected, or were reasonably likely to materially affect, our internal control over financial reporting. We expect a substantial turnover of management personnel and board of directors members during the second quarter of 2012, which may impact our internal control over financial reporting during a transition period.

PART II - OTHER INFORMATION

ITEM 1. LEGAL PROCEEDINGS

On May 4, 2011, Clifton M. (Marty) Bloodworth filed a lawsuit in the State District Court of Midland County, Texas, against Doral West Corp. d/b/a Doral Energy Corp., Patrick Seale and Everett Willard Gray II (Mr. Gray has not yet been served). Mr. Bloodworth alleges that Mr. Gray, as CEO of the Company, made false representations which induced Mr. Bloodworth to enter into an employment contract that was subsequently breached by the Company. The claims that Mr. Bloodworth has alleged are: breach of his employment agreement with Doral, common law fraud, civil conspiracy breach of fiduciary duty, and violation of the Texas Deceptive Trade Practices-Consumer Protection Act. Mr. Bloodworth is seeking damages of approximately $280,000. Mr. Gray and the Company deny that Mr. Bloodworth’s claims have any merit.

On December 12, 2011, Red Mountain Resources, Inc. (“Red Mountain”) and Black Rock Capital, Inc., as direct and indirect shareholders of the Company, filed a lawsuit against the Company in the District Court of Clark County, Nevada as Case No. A-11-653-089-B (the "Action"). The complaint was amended to name the directors of the Company as additional defendants. On April 23, 2012, the Company entered into an agreement (“Settlement Agreement”) with Red Mountain. Pursuant to the Settlement Agreement and effective May 8, 2012, (i) Red Mountain caused a dismissal of the Action with prejudice, (ii) Everett Willard Gray, II, Lawrence J. Risley and Brad E. Heidelberg resigned from the Board of Directors of the Company (with Richard F. LaRoche, Jr. and John W. Hawkins remaining as members of the Board) and (iii) Alan W. Barksdale, Randell K. Ford and Paul N. Vassilakos, each a member of Red Mountain’s board of directors, were appointed as directors of the Company to fill the vacancies. Messrs. Ford, Vassilakos, LaRoche and Hawkins are expected to be independent directors.

Other than the lawsuits described above, we are not currently a party to any legal proceedings.

ITEM 1A. RISK FACTORS

Our business faces many risks. We believe the risks described below are the material risks facing the Company. However, the risks described below may not be the only risks we face. Additional unknown risks or risks that we currently consider immaterial may also impair our business operations. If any of the events or circumstances described below actually occur, our business, financial condition or results of operations could suffer, and the trading price of our shares of common stock could decline significantly. Investors should consider the specific risk factors discussed below, together with the “Cautionary Note Regarding Forward-Looking Information” and the other information contained in this registration statement and the other documents that we file from time to time with the Securities and Exchange Commission.

The following are some of the important factors that could affect our financial performance or could cause actual results to differ materially from estimates contained in our forward-looking statements. We may encounter risks in addition to those described below. Additional risks and uncertainties not currently known to us, or that we currently deem to be immaterial, may also impair or adversely affect our business, financial condition or results of operation.

Risks Relating to Our Business

We have an operating deficit.

Prior to this quarterly period, our operations have not been profitable. Doral Energy Corp. (prior to the merger) incurred losses since inception. We may never be able to achieve sustained profitability.

We have recently merged operations and therefore have a short combined operating history and limited combined audited financial statements.

On January 3, 2011, the Company effected a business combination with Pure L.P. Pure L.P. appointed three new directors, and the Company hired new officers. Because of this recent merger, the Company has a very short operating history for the combined operations. Furthermore, Doral’s fiscal year ended on July 31, 2010, and Pure L.P.’s fiscal year ended on December 31, 2010; therefore the Company does not have consolidated audited financial statements for the newly-combined entity prior to 2011.

Red Mountain Resources, Inc, which controls approximately 29.9% of our Common Stock, may be able to exert significant influence over the Company.

As of April 27, 2012, Red Mountain beneficially owned approximately 29.9% of the existing outstanding shares of our common stock. As a result, Red Mountain has the ability to exercise significant influence over all matters requiring stockholder approval. Red Mountain has appointed three members to the Company's five-member Board, all of which are members of the Board of Red Mountain. The concentration of ownership could have the effect of accelerating, delaying or preventing a change in control of the Company.

The loss of our key persons, or our failure to attract and retain additional personnel could adversely affect our business.

Because we are a small company, our success depends greatly upon the efforts, abilities, and decision-making of our executive officers. Pursuant to the Settlement Agreement, the Company's Chief Executive Officer Everett Willard Gray II and the Company's Chief Operating Officer and President Lawrence J. Risley are resigning effective May 31, 2012. In the event that we are unable to find a suitable replacement to act as the Company's Chief Executive Officer, we may not be able to maintain or develop our business, in which case investors might lose all of their investment.

If we issue additional shares of common stock in the future, this may result in dilution to our existing stockholders.

Our articles of incorporation, as amended, authorize the issuance of 36,363,637 shares of common stock. Our board of directors has the authority to issue additional shares of common stock up to the authorized capital stated in the articles of incorporation. We contemplate that our board of directors may authorize the issuance of some or all of such shares to provide the Company with additional capital or as compensation for consultants and independent contractors providing services to the Company.

The issuance of shares in connection with an offering or as stock compensation may result in a reduction of the book value or market price of the outstanding shares of our common stock. It will also cause a reduction in the proportionate ownership and voting power of all other stockholders.

We have never paid dividends and do not intend to pay any in the foreseeable future, which may delay or prevent recovery of your investment.

We have never paid any cash dividends and currently do not intend to pay any dividends in the foreseeable future. If we do not pay dividends, this may delay or prevent recovery of your investment. To the extent that we require additional funding currently not provided for in our financing plan, it is possible that our funding sources might prohibit the payment of dividends.

We have adopted provisions in our Bylaws that may make it more difficult to acquire the Company.

Our Board of Directors has adopted amendments to our Bylaws providing that shareholders may not act by written consent and that any person who, individually or in association with others, acquires or offers to acquire, directly or indirectly, more than 30% of the outstanding stock of the Company obtains only such voting rights as are conferred by a resolution of the stockholders of the Company. These provisions may make an acquisition of the Company more difficult and therefore may reduce the value of the Company stock.

Risks Relating to Our Industry

Our future performance depends upon our ability to obtain capital to find or acquire additional oil and natural gas reserves that are economically recoverable.

Unless we successfully replace the reserves that are reduced by production, our reserves will decline, resulting eventually in a decrease in oil and natural gas production and lower revenues and cash flows from operations. The business of exploring for, developing or acquiring reserves is capital intensive. Our ability to make the necessary capital investment to maintain or expand our oil and natural gas reserves is limited by our relatively small size. Further, we may commence drilling operations on our properties and any other properties that we acquire in an effort to increase production, which would require more capital than we have available from cash flow from operations or our existing debt facilities. We expect to require additional capital prior to the end of 2012 in order to maintain our reserves and will be required to seek additional sources of financing or limit our participation in additional drilling operations. In addition, our drilling activities are subject to numerous risks, including the risk that no commercially productive oil or gas reserves will be discovered.

The successful implementation of our business plan is subject to risks inherent in the oil and gas business, which if not adequately managed, could result in additional losses.

Our oil and gas operations will be subject to the economic risks typically associated with exploitation and development activities, including the necessity of making significant expenditures to locate and acquire properties and to drill development wells. In addition, the availability of drilling rigs and the cost and timing of drilling, completing and, if warranted, operating wells is often uncertain. In conducting exploitation and development activities, the presence of unanticipated formation pressure or irregularities in formations, miscalculations or accidents may cause our exploitation, development and production activities to be unsuccessful. This could result in a total loss of our investment in a particular well. If exploitation and development efforts are unsuccessful in establishing proved reserves and development activities cease, the amounts accumulated as unproved costs will be charged against earnings as impairments.

In addition, the availability of a ready market for our oil and gas production depends on a number of factors, including the demand for and supply of oil and gas and the proximity of reserves to pipelines and other facilities. Our ability to market such production depends in substantial part on the availability and capacity of gathering systems, pipelines and processing facilities, in most cases owned and operated by third parties. Failure to obtain such services on acceptable terms could materially harm our proposed oil and gas business. We may be required to shut in wells for lack of a market or because of inadequacy or unavailability of pipelines or gathering system capacity. If that occurs, we would be unable to realize revenue from those wells until arrangements are made to deliver such production to market.

Our future performance is dependent upon our ability to identify, acquire and develop oil and gas properties, the failure of which could result in under use of capital and losses.

The future performance of our oil and gas business will depend upon an ability to identify, acquire and develop oil and gas reserves that are economically recoverable. Success will depend upon the ability to acquire working and net revenue interests in properties upon which oil and gas reserves are ultimately discovered in commercial quantities, and the ability to develop prospects that contain proven oil and gas reserves to the point of production. Without successful acquisition, exploitation, and development activities, we will not be able to develop oil and gas reserves or generate revenues. There are no assurances oil and gas reserves will be identified or acquired on acceptable terms, or that oil and gas deposits will be discovered in sufficient quantities to enable us to recover our exploitation and development costs or sustain our business.

The successful acquisition and development of oil and gas properties requires an assessment of recoverable reserves, future oil and gas prices and operating costs, potential environmental risks, and other factors. Such assessments are inexact and uncertain. In addition, no assurances can be given that our exploitation and development activities will result in the discovery of any reserves. Operations may be curtailed, delayed or canceled as a result of lack of adequate capital and other factors, such as lack of availability of rigs and other equipment, title problems, weather, compliance with governmental regulations or price controls, mechanical difficulties, unusual or unexpected formation pressures, and other work interruptions. In addition, the costs of exploitation and development may materially exceed our initial estimates.

The oil and gas exploration and production industry historically is a cyclical industry and market fluctuations in the prices of oil and gas could adversely affect our business.

Prices for oil and gas tend to fluctuate significantly in response to factors beyond our control. These factors include, but are not limited to:

(a)	weather conditions in the United States and elsewhere;
(b)	economic conditions, including demand for petroleum-based products, in the United States and elsewhere;
(c)	actions by OPEC, the Organization of Petroleum Exporting Countries;
(d)	political instability in the Middle East and other major oil and gas producing regions;
(e)	governmental regulations, both domestic and foreign;
(f)	domestic and foreign tax policy;
(g)	the pace adopted by foreign governments for the exploration, development, and production of their national reserves;
(h)	the price of foreign imports of oil and gas;
(i)	the cost of exploring for, producing and delivering oil and gas and the discovery rate of new oil and gas reserves;
(j)	the rate of decline of existing and new oil and gas reserves;
(k)	available pipeline and other oil and gas transportation capacity;
(l)	the ability of oil and gas companies to raise capital;
(m)	the overall supply and demand for oil and gas; and
(n)	the availability of alternate fuel sources.

Changes in commodity prices may significantly affect our capital resources, liquidity and expected operating results. Price changes will directly affect revenues and can indirectly impact expected production by changing the amount of funds available to reinvest in exploration and development activities. Reductions in oil and gas prices not only reduce revenues and profits, but also could reduce the quantities of reserves that are commercially recoverable. Significant declines in prices could result in non-cash charges to earnings due to impairment. Changes in commodity prices may also significantly affect our ability to estimate the value of producing properties for acquisition and divestiture and often cause disruption in the market for oil and gas producing properties, as buyers and sellers have difficulty agreeing on the value of the properties. Price volatility also makes it difficult to budget for and project the return on acquisitions and the development and exploitation of projects. Commodity prices are expected to continue to fluctuate significantly in the future.

Hedging transactions may limit potential gains on increases to oil and gas prices.

From time to time, the Company may enter into hedging transactions. When we do enter into hedging transactions, they are for a portion of our expected production for the purpose of reducing the risk of fluctuations in oil and gas prices. Although these hedging transactions would be expected to provide us with some protection in the event of a decrease in oil and gas prices, they also may limit our potential gains in the event that oil and gas prices increase. Although we are currently engaged in hedging arrangements, if we choose not to engage in hedging arrangements in the future, we may be more adversely affected by changes in oil and natural gas prices than our competitors who engage in hedging arrangements.

We may encounter difficulty in obtaining equipment and services.

Higher oil and natural gas prices and increased oil and natural gas drilling activity generally stimulate increased demand and result in increased prices and unavailability for drilling rigs, crews, associated supplies, equipment and services. While we have recently been successful in acquiring or contracting for services, we could experience difficulty obtaining drilling rigs, crews, associated supplies, equipment and services in the future. These shortages could also result in increased costs or delays in timing of anticipated development or cause interests in oil and natural gas leases to lapse. We cannot be certain that we will be able to implement our drilling plans or at costs that will be as estimated or acceptable to us.

Our ability to produce oil and gas from our oil and gas assets may be adversely affected by a number of factors outside of our control.

The business of exploring for and producing oil and gas involves a substantial risk of investment loss. Drilling oil and gas wells involves the risk that the wells may be unproductive or that, although productive, the wells may not produce oil or gas in economic quantities. Other hazards, such as unusual or unexpected geological formation pressures, fires, blowouts, loss of circulation of drilling fluids or other conditions may substantially delay or prevent completion of any well. Adverse weather conditions can also hinder drilling operations. A productive well may become uneconomic if excessive water or other deleterious substances are encountered that impair or prevent the production of oil or gas from the well. In addition, production from any well may be unmarketable if it is contaminated with water or other deleterious substances. There can be no assurance that oil and gas will be produced from the properties in which we have interests. In addition, the marketability of oil and gas that may be acquired or discovered may be influenced by numerous factors beyond our control. These factors include the proximity and capacity of oil and gas, gathering systems, pipelines and processing equipment, market fluctuations in oil and natural gas prices, taxes, royalties, land lease tenure, allowable production volumes, and environmental protection regulations.

If we are unable to maintain our working interests in leases, our business will be adversely affected.

A portion of our oil and gas assets are held under oil and gas leases. A failure to meet the specific requirements of each lease may cause that lease to terminate or expire. There are no assurances the obligations required to maintain those leases will be met and that we will be able to meet the rental obligations under federal, state and private oil and gas leases. If we are unable to make rental payments and satisfy any other conditions on a timely basis, we may lose our rights in the properties that we may acquire.

Title deficiencies could render our leases worthless.

The existence of a material title deficiency can render a lease worthless and can result in a large expense to our business. In acquiring oil and gas leases or undivided interests in oil and gas leases, we may forgo the expense of retaining lawyers to examine the title to the oil or gas interest to be placed under lease or already placed under lease. Instead, we may rely upon the judgment of oil and gas landmen who perform the field work in examining records in the appropriate governmental office before attempting to place under lease specific oil or gas interest. This is customary practice in the oil and gas industry. As a result, we may be unaware of deficiencies in the marketability of the title to the lease. Such deficiencies could render the lease worthless.

If we fail to maintain adequate operating insurance, our business could be materially and adversely affected. The liability insurance we maintain may not be adequate to cover losses our business may incur.

Our oil and gas operations are subject to risks inherent in the oil and gas industry, such as blowouts, cratering, explosions, uncontrollable flows of oil, gas or well fluids, fires, pollution, earthquakes and other environmental risks. These risks could result in substantial losses due to injury and loss of life, severe damage to and destruction of property and equipment, pollution and other environmental damage, and suspension of operations. We could be liable for environmental damages caused by previous property owners. As a result, substantial liabilities to third parties or governmental entities may be incurred, the payment of which could have a material adverse effect on our financial condition and results of operations. Any prospective drilling contractor or operator which we hire will be required to maintain insurance of various types to cover its operations with policy limits and retention liability customary in the industry. We maintain well control, re-drill, environmental clean-up, and liability insurance on all of our field production and future drilling operations. However, the occurrence of a significant adverse event on such prospects that would happen to be not fully covered by insurance could result in the loss of all or part of our investment in a particular prospect, which could have a material adverse effect on our financial condition and results of operations.

Complying with environmental and other government regulations could be costly and could negatively impact prospective production.

The oil and gas business is governed by numerous laws and regulations at various levels of government. These laws and regulations govern the operation and maintenance of our facilities, the discharge of materials into the environment and other environmental protection issues. Such laws and regulations may, among other potential consequences, require that we acquire permits before commencing drilling and restrict the substances that can be released into the environment with drilling and production activities. Under these laws and regulations, we could be liable for personal injury, clean-up costs and other environmental and property damages, as well as administrative, civil and criminal penalties. Prior to commencement of drilling operations, we may secure limited insurance coverage for sudden and accidental environmental damages as well as environmental damage that occurs over time. However, we do not believe that insurance coverage for the full potential liability of environmental damages is available at a reasonable cost. Accordingly, we could be liable, or could be required to cease production on properties, if environmental damage occurs.

The costs of complying with environmental laws and regulations in the future may harm our business. Furthermore, future changes in environmental laws and regulations could occur, resulting in stricter standards and enforcement, larger fines and liability, and increased capital expenditures and operating costs, any of which could have a material adverse effect on our financial condition or results of operations.

The oil and gas industry is highly competitive, and we may not have sufficient resources to compete effectively.

The oil and gas industry is highly competitive. We will be competing with oil and natural gas companies and other individual producers and operators, many of which have longer operating histories and substantially greater financial and other resources than we have, as well as companies in other industries supplying energy, fuel and other needs to consumers. Larger competitors, by reason of their size and relative financial strength, can more easily access capital markets than we can and may enjoy a competitive advantage in the recruitment of qualified personnel. They may be able to absorb the burden of any changes in laws and regulation in the jurisdictions in which we do business and handle longer periods of reduced prices for oil and gas more easily than we can. Competitors may be able to pay more for oil and gas leases and properties and may be able to define, evaluate, bid for and purchase a greater number of leases and properties than we can. Further, these companies may enjoy technological advantages and may be able to implement new technologies more rapidly than we can. Our ability to acquire oil and gas properties will depend upon our ability to conduct efficient operations, evaluate and select suitable properties, implement advanced technologies and consummate transactions in a highly competitive environment.

Risks Relating to Our Stock

The trading price of our common stock may be volatile, with the result that an investor may not be able to sell any shares acquired at a price equal to or greater than the price paid by the investor.

Our common stock is quoted on the OTCQX under the symbol "XBOR.” Companies quoted on the OTC market have traditionally experienced extreme price and trading volume fluctuations. We have experienced price and volume fluctuations. In addition, our stock price may be adversely affected by factors that are unrelated or disproportionate to our operating performance. The Company is a former shell company and the market fluctuations, as well as general economic, political and market conditions such as recessions, interest rates or international currency fluctuations may adversely affect the market price of our common stock. As a result of this potential price and volume volatility, an investor may have difficulty selling any of our common stock that they acquire at a price equal or greater than the price paid by the investor.

Because our stock is a penny stock, stockholders will be limited in their ability to sell their stock.

The SEC has adopted rules that regulate broker-dealer practices in connection with transactions in penny stocks. Penny stocks are defined in Rule 3a51-1 under the Securities Exchange Act of 1934 (the "Exchange Act") and include equity securities with a price of less than $5.00 and not listed to trade on certain national securities exchanges.

Because our securities constitute "penny stocks" within the meaning of the rules, the rules apply to us and to our securities. The rules may further affect the ability of owners of shares to sell our securities in any market that might develop for them. As long as the trading price of our common stock is less than $5.00 per share, the common stock will be subject to Rule 15g-9 under the Exchange Act. The penny stock rules require a broker-dealer, prior to a transaction in a penny stock, to deliver a standardized risk disclosure document prepared by the SEC that may be found at http://www.sec.gov/investor/schedule 15g.

In addition, the penny stock rules require that prior to a transaction in a penny stock not otherwise exempt from those rules, the broker-dealer must make a special written determination that the penny stock is a suitable investment for the purchaser (based on the purchaser's financial situation, investment experience, and investment objectives) and receive the purchaser's written acknowledgment of the receipt of a risk disclosure statement, a written agreement to transactions involving penny stocks, and a signed and dated copy of a written suitably statement. These disclosure requirements may have the effect of reducing the trading activity in the secondary market for our stock.

ITEM 2. UNREGISTERED SALES OF EQUITY SECURITIES AND USE OF PROCEEDS

No sales of unregistered equity securities occurred during the quarter ended March 31, 2012.

ITEM 6. EXHIBITS

Exhibit
Number		Description of Exhibits
3.1		Amended and Restated Bylaws as amended by Amendments No. 1 and No. 2. (1)
10.1		Consent, Waiver and First Amendment to Amended and Restated Credit Agreement with Texas Capital Bank, N.A. (2)
10.2		First Amendment to Employment Agreement with Everett Willard "Will" Gray II. (2)
10.3		First Amendment to Employment Agreement with Lawrence J. Risley. (2)
10.4		Letter Agreement with Nancy S. Stephenson. (2)
10.5		Agreement with Red Mountain Resources, Inc. (3)
10.6		Second Amendment to Employment Agreement with Everett Willard “Will” Gray II. (3)
10.7		Second Amendment to Employment Agreement with Lawrence J. Risley. (3)
10.8		Amended Letter Agreement with Nancy S. Stephenson. (3)
10.9		Separation Agreement and Mutual Release with Everett Willard “Will” Gray II. (3)
10.10		Separation Agreement and Mutual Release with Lawrence J. Risley. (3)
10.11		Mutual Release with Nancy S. Stephenson. (3)
10.12		Mutual Release with Brad E. Heidelberg. (3)
31.1		Certification of Principal Executive Officer pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
31.2		Certification of Principal Accounting Officer pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
32.1		Certification of Principal Executive Officer pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
32.2		Certification of Principal Accounting Officer pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.

101.INS		XBRL Instance Document
101.SCH		XBRL Taxonomy Extension Schema Document
101.CAL		XBRL Taxonomy Extension Calculation Linkbase Document
101.DEF		XBRL Taxonomy Extension Definition Linkbase Document
101.LAB		XBRL Taxonomy Extension Label Linkbase Document
101.PRE		XBRL Taxonomy Extension Presentation Linkbase Document

(1) Filed as an exhibit to our Annual Report on Form 10-K for the year ended December 31, 2011 on March 14, 2012.

(2) Filed as an exhibit to our Current Report on Form 8-K filed on March 6, 2012.

(3) Filed as an exhibit to our Current Report on Form 8-K filed on April 24, 2012.

SIGNATURES

In accordance with 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.

		CROSS BORDER RESOURCES, INC.

		By	/s/Nancy S. Stephenson
		Name:	Nancy S. Stephenson
		Title:	Chief Accounting Officer
		Date:	May 11, 2012