UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

WASHINGTON, D.C. 20549

FORM 10-Q

(Mark One)

☒	QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
	For the quarterly period ended: September 30, 2014
OR
☐	TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
	For the transition period from __________ to __________

☒

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

~~Commission~~For ~~File~~the ~~Number~~quarterly ~~000-5444~~period ended: December 31, 2014

☐	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 000-54444

RED MOUNTAIN RESOURCES, INC.

(Exact name of registrant as specified in its charter)

Texas	27-1739487
(State or other jurisdiction of incorporation or organization)	(I.R.S. Employer Identification No.)
2515 McKinney Avenue, Suite 900 Dallas, TX	75201
(Address of principal executive offices)	(Zip Code)

14282 Gillis Road

Farmers Branch, TX

75244

(Address of principal executive offices)

(Zip Code)

(214) 871-0400

(Registrant’s telephone number, including area code)

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

Indicate by check mark whether the registrant has submitted electronically and posted on its corporate website, 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 is required to submit and post such files). Yes ☒ 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. (Check one):

Large accelerated filer ☐ Accelerated filer ☒☐ Non-accelerated filer ☐ (Do not check if a smaller reporting company) Smaller reporting company ☐☒

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

As of November 141, ~~2014~~2015, the registrant had 14,857,488 shares of common stock outstanding.

TABLE OF CONTENTS

PART I. FINANCIAL INFORMATION
Item 1.	Financial Statements	1
	Condensed Consolidated Balance Sheets as of September 30, 2014 and June 30, 2014	1
	Condensed Consolidated Balance Sheets as of December 31, 2014 and June 30, 2014 (unaudited)	1
	Condensed Consolidated Statements of Operations for Each of the Three Months Ended September 30, 2014 and 2013	2
	Condensed Consolidated Statements of Operations for Each of the Three and Six Months Ended December 31, 2014 and 2013 (unaudited)	2
	Condensed Consolidated Statements of Cash Flows for Each of the Three Months Ended September 30, 2014 and 2013	3
	Condensed Consolidated Statements of Cash Flows for the Six Months Ended December 31, 2014 and 2013 (unaudited)	3
	Condensed Consolidated Statements of Stockholders’ Equity for the Three Months Ended September 30, 2014	4
	Condensed Consolidated Statements of Stockholders’ Equity for the Six Months Ended December 31, 2014 (unaudited)	4
	Notes to Condensed Consolidated Financial Statements	5
Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	1619
Item 3.	Quantitative and Qualitative Disclosures About Market Risk	2425
Item 4.	Controls and Procedures	25
PART II. OTHER INFORMATION
Item 1.	Legal Proceedings	26
Item 1A.	Risk Factors	26
Item 2.	Unregistered Sales of Equity Securities and Use of Proceeds	2728
Item 3.	Defaults Upon Senior Securities	2728
Item 4.	Mine Safety Disclosures	2728
Item 5.	Other Information	2728
Item 6.	Exhibits	28

PART I. FINANCIAL INFORMATION

Item 1.

Financial Statements

Red Mountain Resources, Inc. and Subsidiaries

Condensed Consolidated Balance Sheets

(unaudited)

(in thousands)

	September 30,			June 30,
		December 31, 2014			June 30, 2014
	2014			2014
		(unaudited)
ASSETS
Current Assets:
Cash and cash equivalents	$	1,~~000~~431		$	1,682
Accounts receivable - oil and natural gas sales		2,772			3,186
Accounts receivable – oil and natural gas sales		2,787			3,186
Accounts receivable – joint interest		~~764~~1,377			1,645
Prepaid expenses and other current assets		551			527
Debt issuance costs		—			—
Commodities derivative asset – current		189			37
Prepaid expenses and other current assets		578			527
Deferred tax asset – current		277			368
Commodities derivative asset – current		303			37
Total current assets		5,553			7,445
Deferred tax asset – current		—			368
Assets held for sale		25,000			—
Total current assets		31,476			7,445
Long-Term Investments:
Debentures – held to maturity		41,~~820~~018			4,820
Oil and Natural Gas Properties, Successful Efforts Method:
Proved properties		8548,~~146~~961			82,362
Unproved properties		1910,~~043~~506			19,109
Other property and equipment		1,~~139~~213			1,196
Less accumulated depreciation, depletion, amortization and impairment		(21,977	)		(19,497	)
Less accumulated depreciation, depletion and impairment		(29,196	)		(19,497	)
Oil and natural gas properties, net		8331,~~351~~484			83,170
Other Assets:
Restricted cash, long-term		493			493
Commodities derivative asset, net of current portion		—			—
Debt issuance costs, net of current portion		975			1,101
Restricted cash, long-term		474			493
Security deposit and other assets		181			197
Debt issuance costs		861			1,101
Total Assets	$	95,373		$	97,226
Security deposit and other assets		380			197
Total Assets	$	65,693		$	97,226
LIABILITIES AND STOCKHOLDERS’ EQUITY
Current Liabilities:
Accounts payable	$	48,~~467~~799		$	3,536
Revenues payable		1,~~154~~014			1,673
Accrued expenses		2,605			2,035
Preferred dividend payable		21			179
Accrued expenses		2,298			2,035
Commodities derivative liability		—			121
Dividend payable		175			179
Line of credit – current		27,800			—
Taxes payable		3			—
Asset retirement obligation – current		2,901			214
Asset retirement obligation – current		178			214
Environmental remediation liability – current		2,057			2,067
Line of credit – current		26,800			—
Total current liabilities		44,890			9,825
Total current liabilities		37,439			9,825
Long-Term Liabilities:
Mandatorily redeemable preferred stock, net of discount of $1,464 and $1,561		4,898			4,801
Line of credit, net of current portion		—			26,800
Deferred tax liability – long-term		330			409
Mandatorily redeemable preferred stock, net of discount of $1,367 and $1,561 respectively		4,995			4,801
Asset retirement obligation, net of current portion		5,570			5,531
Stock issuance liability		50			—
Total long-term liabilities		10,798			37,541
Deferred tax liability – long-term		—			409
Total Liabilities		48,237			47,366
Asset retirement obligation, net of current portion		2,900			5,531
Total long-term liabilities		7,945			37,541
Total Liabilities		52,835			47,366
Commitments and Contingencies (Note 10)
Stockholders’ Equity:
Common stock, $0.00001 par value; 50,000 shares authorized; 14,857 shares issued and 14,790 shares outstanding as of September 30, 2014 and June 30, 2014		1			1
Common stock, $0.00001 par value; 50,000 shares authorized; 14,857 shares issued and 14,857 shares outstanding as of December 31, 2014 and June 30, 2014		1			1
Noncontrolling interest		63,~~244~~486			6,076
Additional paid-in capital		78,105			78,105
Accumulated deficit		(3768,~~214~~734	)		(34,322	)
Total stockholders’ equity		4712,~~136~~858			49,860
Total Liabilities and Stockholders’ Equity	$	9565,~~373~~693		$	97,226

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

Red Mountain Resources, Inc. and Subsidiaries

Condensed Consolidated Statements of Operations

(Unaudited)

(in thousands, except per share amounts)

	Three Months Ended September 30,
	Three Months Ended,						Six Months Ended,
	2014			2013
		December 31, 2014			December 31, 2013			December 31, 2014			December 31, 2013
Revenue:
Oil and natural gas sales	$	53,~~272~~390		$	54,~~774~~467		$	8,661		$	10,241
Operating Expenses:
Exploration expense		~~250~~478			~~101~~327			1,261			428
Dry hole expense		533			—
Production taxes		236			573			655			1,178
Production taxes		419			606
Lease operating expenses		1,089			707			2,245			1,455
Lease operating expenses		1,156			747
Natural gas transportation and marketing expenses		39			37			137			74
Natural gas transportation and marketing expenses		98			38
Depreciation, depletion, amortization and impairment		30,602			2,162			33,011			4,252
Depreciation, depletion, amortization and impairment		2,409			2,091
Accretion of discount on asset retirement obligation		34			68			68			135
Accretion of discount on asset retirement obligation		34			67
General and administrative expense		1,410			1,915			4,109			3,859
General and administrative expense		2,689			1,942
Total operating expenses		33,888			5,789			41,486			11,381
Total operating expenses		7,588			5,592
Income (Loss) from Operations		(30,498	)		(1,322	)		(32,825	)		(1,140	)
Income (Loss) from Operations		(2,316	)		182
Other Income (Expense):
Other Income (Expense):
Change in fair value of derivative liability		697			—			965			—
Interest expense		(~~665~~690	)		(~~927~~887	)		(1,355	)		(1,815	)
Gain (loss) on commodity derivatives		269			(384	)
Unrealized loss on debentures		(3,787	)		—			(3,787	)		—
Total Other Expense		(396	)		(1,311	)
Unrealized gain (loss) on commodity derivatives		—			64			—			(231	)
Loss Before Income Taxes		(2,712	)		(1,129	)
Realized gain (loss) on commodity derivatives		—			37			—			(51	)
Income tax provision		(12	)		—
Total Other Expense		(3,780	)		(786	)		(4,177	)		(2,097	)
Net loss		(2,724	)		(1,129	)
Loss Before Income Taxes		(34,278	)		(2,108	)		(37,002	)		(3,237	)
Net income attributable to noncontrolling interest		168			146
Income tax provision		—			—			—			—
Net loss attributable to Red Mountain Resources, Inc.	$	(2,892	)	$	(1,275	)
Net loss		(34,278	)		(2,108	)		(37,002	)		(3,237	)
Basic and diluted net loss per common share	$	(0.19	)	$	(0.10	)
Net income (loss) attributable to non-controlling interest		(2,759	)		97			(2,591	)		243
Basic and diluted weighted average common shares outstanding		14,857			12,922
Net loss attributable to Red Mountain Resources, Inc.	$	(31,519	)	$	(2,205	)	$	(34,411	)	$	(3,480	)
Basic and diluted net loss per common share	$	(2.12	)	$	(0.16	)	$	(2.32	)	$	(0.26	)
Basic and diluted weighted average common shares outstanding		14,857			13,372			14,857			13,147

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

Red Mountain Resources, Inc. and Subsidiaries

Condensed Consolidated Statements of Cash Flows

(Unaudited)

(in thousands)

	Three Months Ended September 30,
	Six Months Ended,
	2014			2013
		December 31, 2014			December 31, 2013
Cash Flow From Operating Activities:
Net loss	$	(237,~~724~~002	)	$	(13,~~129~~237	)
Adjustments to reconcile net loss to net cash provided by (used in) operating activities:
Deferred income tax expense		12			—
Depreciation, depletion, amortization and impairment		33,011			4,252
Depreciation, depletion, amortization and impairment		2,409			2,091
Debentures return of capital		15			—
Amortization of debt issuance costs		~~223~~434			~~510~~894
Accretion of discount on asset retirement obligation		3468			67135
Dividend accrued for mandatorily redeemable preferred stock		(4158	)		~~149~~249
Change in commodity derivatives		(273	)		382
Change in deferred tax asset		91			—
Change in deferred tax liability		(79	)		—
Unrealized gain on derivative liability		(337	)		318
Loss on debentures		3,787			—
Change in working capital:
Accounts receivable – oil and natural gas sales		414			883
Accounts receivable - oil and natural gas sales		399			2,301
Accounts receivable – other		881			1,254
Accounts receivable - other		523			664
Prepaid expenses and other assets		(6233	)		~~687~~434
Accounts payable		~~411~~(926	)		(42,~~733~~674	)
Accrued expenses		561			(543	)
Restricted cash		19			(13	)
Net cash provided by (used in) operating activities		1,938			(382	)
Accrued expenses		372			1,629
Net cash provided by (used in) operating activities		(69	)		4,952
Cash Flow From Investing Activities:
Additions to oil and natural gas properties		(2,561	)		(1,494	)
Net additions to oil and natural gas properties		(1,050	)		(7,076	)
Additions to other property and equipment		(2396	)		(71139	)
Settlement of asset retirement obligations		(36	)		—
Net cash used in investing activities		(21,~~620~~182	)		(17,~~565~~215	)
Cash Flow From Financing Activities:
Proceeds from issuance of common stock, net of issuance costs		—			3,605
Proceeds from issuance of preferred stock, net of issuance costs		—			7,~~095~~068
Exercise of warrants		—			—
Net borrowings under line of credit		1,000			—
Proceeds from notes payable		—			—
Payments on line of credit		—			(5,000	)
Payments on notes payable		—			(~~500~~2,000	)
Net cash provided by financing activities		—1,000			53,~~200~~673
Net change in cash and equivalents		~~(682~~251	)		31,~~253~~410
Cash at beginning of period		1,682			456
Cash at end of period	$	1,~~000~~431		$	31,~~709~~866
Supplemental Disclosure of Cash Flow Information:
Supplemental Disclosure of Cash Flow Information
Cash paid during the period for interest	$	~~446~~—		$	~~536~~1,220
Non-Cash Transactions:
Non-Cash Transactions
Change in asset retirement obligation estimate	$	5—		$	2257
Issuance of shares for debentures	$	—		$	541
Issuance of warrants with preferred stock	$	—		$	2,395

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

Red Mountain Resources, Inc. and Subsidiaries

Condensed Consolidated Statements of Stockholders’ Equity

(Unaudited)

(in thousands)

	Common Stock
							Additional Paid-in Capital			Retained Earnings (Accumulated Deficit)			Noncontrolling Interest			Total
	Shares			Amount				Additional Paid-in Capital				Accumulated Deficit				Noncontrolling Interest		Total
		Common Stock
Balance at June 30, 2014		14,857		$	1.487			$	78,105			$	(34,322	)		$	6,076	$	49,860
		Shares		Amount
Net income (loss)		—			—				—				(2,892	)			168		(2,724	)
Balance at June 30, 2014		14,857	$	1.487		$	78,105		$	(34,322	)	$	6,076		$	49,860
Balance at September 30, 2014		14,857		$	1.487			$	78,105			$	(37,214	)		$	6,244	$	47,136
Net loss		—		—			—			(34,412	)		(2,590	)		(37,002	)
Balance at December 31, 2014		14,857	$	1.487		$	78,105		$	(68,734	)	$	3,486		$	12,858

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

Red Mountain Resources, Inc. and Subsidiaries

Notes to Condensed Consolidated Financial Statements

(Unaudited)

1. Organization

Red Mountain Resources, Inc. is a Texas corporation formed on January 23, 2014. On January 31, 2014, the Company changed its state of incorporation from the State of Florida to the State of Texas by merging Red Mountain Resources, Inc., a Florida corporation (“RMR FL”), with and into Red Mountain Resources, Inc., a Texas corporation. RMR FL was formed in January 2010 and acquired Black Rock Capital, LLC in a reverse merger effective July 1, 2011. Unless the context otherwise requires, the terms “Red Mountain” and “Company” refer to Red Mountain Resources, Inc. and its consolidated subsidiaries.

The Company is a Dallas-based ~~growth-oriented energy~~ company ~~engaged in the acquisition, development and exploration of~~ with oil and natural gas properties in ~~established basins with demonstrable prolific producing zones. Currently,~~ the ~~Company has established acreage positions and production in the~~ Permian Basin of West Texas and Southeast New Mexico, ~~and~~ the onshore Gulf Coast of Texas. ~~Additionally, the Company has an established~~ and ~~growing acreage position in~~ Kansas.

Reverse stock split

On January 31, 2014, RMR FL effected a reverse stock split of RMR FL’s common stock, par value $0.00001 per share (“RMR FL Common Stock”), at an exchange ratio of 1-for-10 (the “Reverse Stock Split”), together with a proportional reduction in the number of authorized shares of RMR FL Common Stock from 500.0 million shares to 50.0 million shares. The par value of RMR FL Common Stock did not change as a result of the Reverse Stock Split. As of January 31, 2014, every ten shares of RMR FL Common Stock were combined into one share of RMR FL Common Stock, reducing the number of outstanding shares of RMR FL Common Stock from approximately 134.0 million to approximately 13.4 million. In addition, a proportionate adjustment was made to the per share exercise price and the number of shares issuable upon the exercise of all outstanding warrants to purchase shares of RMR FL Common Stock. All share and per share amounts and calculations have been retroactively adjusted to reflect the effects of the Reverse Stock Split.

2. Going Concern

These consolidated financial statements have been prepared on the basis of accounting principles applicable to a going concern. These principles assume that the Company will be able to realize its assets and discharge its obligations in the normal course of operations for the foreseeable future.

The Company incurred a net loss of $234.9 4 million during the ~~three~~six months ended ~~September~~December 3031, 2014. At ~~September~~December 3031, 2014, the outstanding principal amount of the Company’s debt was $3132.78 million, net of an aggregate discount of $1.54 million, and the Company had a working capital deficit of $3113.94 million. Of the outstanding debt, $2627.8 million is outstanding under the Company’s Credit Facility (as defined below). Of the $3113.9 4 million working capital deficit at ~~September~~December 3031, 2014, $2627.8 million relates to the reclassification of the full amount of the outstanding borrowings under the Company'’s Credit Facility from a long-term liability to a short-term liability on its Consolidated Balance Sheets as of ~~September~~December 3031, 2014. The Company is currently in default under the Credit Facility, and the lender has the right to accelerate all amounts outstanding under the Credit Facility upon notice to the borrowers. The Company is in discussions with the lender regarding either a waiver of the non-compliance or an amendment to the credit agreement to cure the non-compliance. While the Company anticipates obtaining a waiver from the lender, it cannot provide any assurance that these negotiations will be successful. The Company is exploring available financing options, including the sale of debt or equity. If the Company is unable to finance its operations on acceptable terms or at all, its business, financial condition and results of operations may be materially and ~~adversely~~ adversely affected. As a result of recurring losses from operations and a working capital deficiency, there is substantial doubt regarding the Company’s ability to continue as a going concern. The accompanying financial statements do not include ~~any~~ any adjustments to reflect the possible future effects on the recoverability and classification of assets or the amount and ~~classification~~ classification of liabilities that may result from the possible inability of the Company to continue as a going concern.

3. Significant Accounting Policies

Basis of Presentation

The condensed consolidated financial statements include the accounts of Red Mountain Resources, Inc. and its subsidiaries. The condensed consolidated financial statements and related footnotes are presented in accordance with generally accepted accounting principles in the United States (“GAAP”).

The Company has prepared the accompanying unaudited interim financial statements pursuant to the rules and regulations of the Securities and Exchange Commission (the “SEC”), and in the opinion of management, such financial statements reflect all adjustments necessary to present fairly the consolidated financial position of the Company at ~~September~~December 3031, 2014 and ~~June 30, 2014 and~~ its results of operations and cash flows for the periods presented. The Company has omitted certain information and disclosures normally included in annual financial statements prepared in accordance with GAAP pursuant to those rules and regulations, although the Company believes that the disclosures it has made are adequate to make the information presented not misleading. These unaudited interim financial statements should be read in conjunction with the Company’s audited consolidated financial statements and related footnotes included in its most recent Annual Report on Form 10-K.

In preparing the accompanying financial statements, management has made certain estimates and assumptions that affect reported amounts in the financial statements and disclosures. The results of operations for the interim periods are not necessarily indicative of the results the Company expects for the full fiscal year. The Company has not made any changes in its significant accounting policies from those disclosed in its most recent Annual Report on Form 10-K.

The Company effected a reverse stock split of its outstanding common stock at a ratio of one-for-ten (1:10) on January 31, 2014. Retroactive application of the reverse stock split is required and all share and per share information included for all periods presented in these financial statements reflect the reverse stock split.

Business Combinations

The Company accounts for business combinations under the acquisition method of accounting in accordance with Accounting Standards Codification (“ASC”) Topic 805, Business Combinations (“ASC 805”). The acquisition method requires that assets acquired and liabilities assumed including contingencies be recorded at their fair values as of the acquisition date. The Company has finalized the determination of the fair values of the assets acquired and liabilities assumed for Cross Border Resources, Inc. (“Cross Border”).

Noncontrolling Interests

Subsequent to January 28, 2013, the Company accounts for the noncontrolling interest in Cross Border ~~Resources, Inc. (“Cross Border”)~~ in accordance with ASC Topic 810, Consolidation (“ASC 810”). ASC 810 establishes accounting and reporting standards for ownership interests in subsidiaries held by parties other than the parent, the amount of consolidated net income attributable to the parent and to the noncontrolling interest, changes in a parent’s ownership interest and the valuation of retained noncontrolling equity investments when a subsidiary is deconsolidated. ASC 810 also establishes reporting requirements that provide sufficient disclosures that clearly identify and distinguish between the interest of the parent and the interests of the noncontrolling owner. In addition, this guidance provides for increases and decreases in the Company’s controlling financial interests in consolidated subsidiaries to be reported in equity similar to treasury stock transactions.

~~Debentures~~Investments in Non-Performing ~~Held to Maturity~~Debentures

The Company’s investments in non-performing debentures were initially recorded at cost which the Company believes was fair value. Management estimated cash flows expected to be collected considering the contractual terms of the loans, the nature and estimated fair value of collateral, and other factors it deemed appropriate. The estimated fair value of the loans at acquisition was significantly less than the contractual amounts due under the terms of the loan agreements.

Since, at the acquisition date, the Company expected to collect less than the contractual amounts due under the terms of the loans based, at least in part, on the assessment of the credit quality of the borrower, the loans are accounted for in accordance with ASC Topic 310-30, Loans and Debt Securities Acquired with Deteriorated Credit Quality (“ASC 310-30”). The difference between the contractually required payments on the loans as of the acquisition date and the total cash flows expected to be collected, or non-accretable difference, is not recognized and totaled $2.15 million ~~and $2.1 million~~, plus accrued interest in arrears, as of ~~September~~each 30of December 31, 2014 and ~~June 30~~2013, ~~2014,~~ respectively.

Debentures are classified as non-accrual ~~when~~ when management is unable to reasonably estimate the timing or amount of cash flows expected to be collected from the debentures or or has serious doubts about further collectability of principal or interest. As of ~~September~~December 3031, 2014 and June 30, 2014, all of the Company’s debentures were on non-accrual status since the borrower remains under the supervision of the bankruptcy court.

The Company periodically re-evaluates ~~cash~~ cash flows expected to be collected for each debenture based upon all available information as of the measurement date. Subsequent increases in cash flows expected to be collected are recognized prospectively through an adjustment to the debenture’s yield over its remaining life, which may result in a reclassification from non-accretable difference to accretable yield. Subsequent decreases in cash flows expected to be collected are evaluated to determine whether a provision for loan loss should be established. If decreases in expected cash flows result in a decrease in the estimated fair value of the debenture below its amortized cost, the debenture is deemed to be impaired, and the Company will record a provision for impairment to write the debenture down to its estimated fair value. The Company recorded impairment on the debentures of approximately $3.8 million during the six months ended December 31, 2014 while the Company did not record anany impairment expense on the debentures during the ~~three~~six months ended ~~September~~December 3031, ~~2014~~2013.

The Company’s investments in non-performing debentures are classified as held to maturity because the Company has the intent and ability to hold them until maturity.

Recent Accounting Pronouncements

In ~~August~~April 2014, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update (“ASU”) 2014-1508, ~~Presentation~~Reporting Discontinued ofOperations ~~Financial~~and ~~Statements~~Disclosures -of ~~Going~~Components ~~Concern~~of an Entity (~~Subtopic 205~~“ASU 2014-4008”):. ~~Disclosure~~ASU 2014-08 revises the definition of ~~Uncertainties~~discontinued ~~about~~operations anby ~~Entity’s~~limiting ~~Ability~~discontinued operations reporting to ~~Continue~~disposals asof acomponents ~~Going~~of ~~Concern~~an ~~(“ASU~~entity ~~2014-15”),~~that represent ~~which~~strategic ~~requires~~shifts ~~management~~that tohave ~~evaluate,~~(or atwill ~~each~~have) ~~annual~~a ~~and~~major ~~interim~~effect ~~reporting~~on ~~period,~~an ~~whether~~entity’s ~~there~~operations ~~are~~and ~~conditions~~financial orresults, ~~events~~removing ~~that~~the lack ~~raise~~of ~~substantial~~continuing ~~doubt~~involvement ~~about~~criteria ~~the~~and ~~entity’s~~requiring ~~ability~~discontinued tooperations ~~continue~~reporting asfor athe ~~going~~disposal ~~concern~~of ~~within~~an ~~one~~equity ~~year~~method ~~after~~investment that meets the ~~date~~definition ~~the~~of ~~financial statements~~discontinued ~~are~~operations. ~~issued~~The ~~and~~update ~~provide~~also ~~related~~requires expanded disclosures. ~~ASU~~for ~~2014-15~~discontinued isoperations, including ~~effective~~disclosure ~~for~~of ~~annual~~pretax ~~periods~~profit ~~ending~~or ~~after~~loss ~~December~~of ~~15,~~an ~~2016 and~~individually ~~interim~~significant ~~periods~~component ~~thereafter,~~of ~~and~~an ~~early~~entity ~~adoption~~that isdoes ~~permitted~~not qualify for discontinued operations reporting. The ~~Company~~update is ~~currently~~effective inprospectively ~~the~~to ~~process~~all ofperiods ~~evaluating~~beginning after December 15, 2014. Currently, the ~~impact~~Company does not expect the adoption of ASU 2014-1508 ~~will~~to have ona ~~the~~material ~~Company’s~~impact ~~consolidated~~on our financial statements or results of operations.

Effective January 1, 2016, the Company will be required to adopt the amended guidance of ASC Topic 718, Compensation - Stock Compensation, which seeks to resolve the diversity in practice that exists when accounting for share-based payments. The amended guidance requires a performance target that affects vesting and that could be achieved after the requisite service period to be treated as a performance condition.

The Company will be required to adopt the amended guidance either prospectively to all awards granted or modified after the effective date or retrospectively to all awards with performance targets that are outstanding as of the beginning of the earliest annual period presented in the consolidated financial statements and to all new or modified awards thereafter. The Company does not expect the adoption of this amended guidance to impact financial results.

Effective January 1, 2016, the Company will be required to adopt the amended guidance of ASC 810, which seeks to improve targeted areas of the consolidation guidance for legal entities such as limited partnerships, limited liability corporations, and securitization structures. The amended guidance changes the analysis that a reporting entity must perform to determine whether it should consolidate certain types of legal entities. The changes include, among others, modification of the evaluation whether limited partnerships and similar legal entities are variable interest entities or voting interest entities and elimination of the presumption that a general partner should consolidate a limited partnership. The Company will be required to adopt ASC 810 either on a full retrospective basis to each prior reporting period presented or on a modified retrospective basis with the cumulative effect of initially applying the new guidance recognized at the date of initial application. The Company has not yet completed its assessment of the impact of the amended guidance on its financial statements but does not expect the adoption of this amended guidance to have a significant impact on financial results.

Effective January 1, 2017, the Company will be required to adopt the new guidance of ASC Topic 606, Revenue from Contracts with Customers (“ASC 606”), which will supersede the revenue recognition requirements in ASC Topic 605, Revenue Recognition. ASC 606 requires the Company to recognize revenue to depict the transfer of promised goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods or services. The new guidance requires the Company to apply the following steps: (1) identify the contract with a customer; (2) identify the performance obligations in the contract; (3) determine the transaction price; (4) allocate the transaction price to the performance obligations in the contract; and (5) recognize revenue when, or as, the Company satisfies a performance obligation. The Company will be required to adopt ASC 606 either on a full retrospective basis to each prior reporting period presented or on a modified retrospective basis with the cumulative effect of initially applying the new guidance recognized at the date of initial application. If the Company elects the modified retrospective approach, it will be required to provide additional disclosures of the amount by which each financial statement line item is affected in the current reporting period, as compared to the guidance that was in effect before the change, and an explanation of the reasons for significant changes. The Company has not yet completed its assessment of the impact of the new guidance on its consolidated financial statements. On April 29, 2015, the FASB issued a proposed ASU to defer the effective date of ASC 606 to annual reporting periods beginning after December 15, 2017, including interim reporting periods within that reporting period. If the FASB proceeds with the deferral of the effective date as proposed, this will mean the Company will be required to adopt the new guidance of ASC 606 effective January 1, 2018.

In August 2014, the FASB issued ASU 2014-15, Disclosure of Uncertainties about an Entity’s Ability to Continue as a Going Concern (“ASU 2014-15”), an amendment to ASC Topic 205, Presentation of Financial Statements. This update provides guidance on management’s responsibility in evaluating whether there is substantial doubt about an entity’s ability to continue as a going concern and to provide related footnote disclosures. ASU 2014-15 is effective for annual periods ending after December 15, 2016, and for annual and interim periods thereafter. Early adoption is permitted. The Company does not expect the adoption of ASU 2014-15 to have a material impact on our financial statements or results of operations. If events occur in future periods that could affect our ability to continue as a going concern, we will provide the disclosures required by ASU 2014-15.

The Company has reviewed other recently issued, but not yet adopted, accounting standards in order to determine their effects, if any, on our results of operations, financial position and cash flows. Based on that review, we believe that none of these recent pronouncements will have a significant effect on our current or future earnings or operations.

4. Oil and Natural Gas Properties and Other Property and Equipment

Oil and Natural Gas Properties

The following table sets forth the capitalized costs under the successful efforts method for oil and natural gas properties:

	September 30,			June 30,
(in thousands)	December 31, 2014			June 30, 2014
	2014			2014
(in thousands)
Oil and natural gas properties:
Proved	$	8548,~~146~~961		$	82,362
Unproved		1910,~~043~~506			19,109
Total oil and natural gas properties		~~104~~59,~~189~~467			101,471
Less accumulated depletion and impairment		(2128,~~456~~748	)		(19,138	)
Net oil and natural gas properties capitalized costs	$	8230,~~733~~719		$	82,333

AtDuring ~~September~~the 30three and six months ended December 31, 2014 and ~~June~~December 3031, ~~2014~~2013, the ~~capitalized~~ ~~costs of the~~ Company’s ~~oil~~did ~~and~~not ~~natural~~incur ~~gas~~any ~~properties~~significant ~~included~~exploratory ~~(i)~~drilling ~~$38~~costs.8 ~~million~~The ~~and~~Company ~~$39.0~~had ~~million,~~no ~~respectively,~~transfers ~~relating~~of toexploratory ~~acquisition~~well costs ofto proved properties ~~which~~during ~~are being amortized by~~ the ~~unit-of-production~~three ~~method using total proved reserves~~ and ~~(ii)~~six ~~$45.8~~months ~~million~~ended ~~and~~December ~~$39.6 million~~31, ~~respectively,~~2014 ~~relating to exploratory well costs~~ and ~~additional~~December ~~development costs~~31, ~~which are being amortized by the unit-of-production method using proved developed reserves~~2013.

~~During~~Capitalized ~~the~~costs ~~three~~related ~~months~~to ~~ended~~proved oil ~~September~~and 30natural gas properties, ~~2014~~including wells and ~~2013~~related equipment and facilities, are evaluated for impairment based on the Company’s analysis ~~incurred~~of $0undiscounted future net cash flows.5 ~~million~~If ~~and~~undiscounted $0future ~~million~~net incash ~~exploratory~~flows ~~drilling~~are insufficient to recover the net capitalized costs. ~~The~~related to proved properties, then the Company recognizes an impairment charge in income equal to the difference between ~~transferred~~the ~~$30,000~~carrying value and $0the estimated fair value of ~~exploratory~~the ~~well~~properties. Estimated fair values are determined using discounted cash flow models. The discounted cash flow models include management’s estimates of future oil and natural gas production, operating and development costs toand discount rates. The Company recorded a $29.0 million impairment on its proved properties during the three and six months ended ~~September~~December 3031, 2014 , while no such impairment was recorded during the three and ~~2013,~~six ~~respectively~~months ended December 31, 2013.

~~The~~Assets ~~Company~~are ~~recorded~~classified anas ~~impairment~~held offor ~~approximately $36,000~~sale ~~related~~when the Company commits to ~~its~~a ~~unproved~~plan ~~oil~~to sell the assets and ~~natural~~there ~~gas~~is ~~properties~~reasonable ~~during~~certainty that the ~~three~~sale ~~months~~will ~~ended~~take ~~September~~place 30within one year. Upon classification as held for sale, ~~2014~~long-lived assets are no longer depreciated or depleted, and a measurement for impairment is performed to identify and expense any excess of carrying value over fair value less estimated costs to sell.

~~Capitalized~~The ~~costs~~accompanying ~~related~~balance tosheets ~~proved~~present ~~oil~~$25 ~~and natural~~million ~~gas~~of ~~properties,~~assets ~~including~~held ~~wells~~for ~~and related equipment and facilities~~sale, ~~are~~net ~~evaluated for impairment based on the Company’s analysis~~ of ~~undiscounted future net cash flows. If undiscounted future net cash flows are insufficient to recover the net capitalized~~accumulated ~~costs~~depreciation, ~~related to proved properties~~depletion, ~~then the Company recognizes an impairment charge in income equal to the difference between the carrying value~~ and ~~the~~amortization ~~estimated~~expense, ~~fair~~which ~~value~~consists of ~~the~~our ~~properties. Estimated fair values are determined using discounted cash flow models. The discounted cash flow models include management’s estimates of future~~ oil and ~~natural~~ gas ~~production,~~properties ~~operating and~~sold ~~development costs and discount rates. The Company did not record any impairment charges~~ on ~~its~~April ~~proved properties for the three months ended September 30~~21, ~~2014 and 2013~~2015.

Other Property and Equipment

The historical cost of other property and equipment, presented on a gross basis with accumulated depreciation and amortization is summarized as follows:

	September 30,			June 30,
(in thousands)	December 31, 2014			June 30, 2014
	2014			2014
Other property and equipment	$	1,213		$	1,196
(in thousands)
Less accumulated depreciation and amortization		(448	)		(359	)
Other property and equipment	$	1,139		$	1,196
Net property and equipment	$	765		$	837
Less accumulated depreciation and amortization		(521	)		(359	)
Net property and equipment	$	618		$	837

5. Asset Retirement Obligations

The following table summarizes the changes in in the Company’s asset retirement obligations (“AROs”) for the ~~periods~~six ~~indicated~~months ended December 31, 2014 and the fiscal year ended June 30, 2014:

	Three Months Ended September 30,			Fiscal Year EndedJune 30,
(in thousands)	Six Months Ended December 31, 2014			Fiscal Year Ended June 30, 2014
	2014			2014
(in thousands)
Asset retirement obligations at beginning of period	$	5,745		$	5,020
Liabilities incurred		524			75
Liabilities settled		(36	)		(2	)
Accretion expense		34			267
Acquisitions		—			—
Accretion expense		68			267
Revisions in estimated liabilities		—			385
Asset retirement obligations at end of period		5,~~748~~801			5,745
Less: current portion		~~178~~2,901			214
Long-term portion	$	52,~~570~~900		$	5,531

During the ~~three~~fiscal ~~months~~year ended ~~September~~June 30, ~~2013,~~ 2014, the Company recorded an upward ~~revision~~revisions to previous estimates for its ARO primarily due to changes in the estimated future cash outlays. There were no revisions to ARO during the six months ended December 31, 2014.

6. Derivatives

At ~~September~~December 3031, 2014, the Company had the ~~following~~ following commodity derivatives positions outstanding:

Commodity and Time Period	Contract Type	Volume Transacted	Contract Price
Crude Oil
October 1, 2014―November 30, 2014	Swap	2,000 Bbls/month	$	93.50/Bbl
January 1, 2014―January 31, 2015	Put	6,000 Bbls/month	$	95.00/Bbl
October 1, 2014―December 31, 2014	Put	1,979-8,330 Bbls/month		$95.00 - $100.00/Bbl
October 1, 2014―January 31, 2015	Put	6,000 Bbls/month	$	95.00/Bbl

The following table summarizes the fair value of the Company’s open commodity derivatives as of ~~September~~December 3031, 2014 and June 30, 2014:

	Balance Sheet Location	Fair Value	~~Fair Values~~
			September 30,		June 30,
		December 31,		June 30,
			2014		2014
(in thousands)		2014		2014
(in thousands)
Derivatives not designated as hedging instruments
Commodity derivatives	Commodities derivative asset	$	~~189~~303	$	37
Commodity derivatives	Commodities derivative liability	$	—	$	(121	)

The following ~~table~~tables ~~summarizes~~summarize the change in in the fair value of the Company’s commodity derivatives:

	Income Statement Location	Three Months Ended ~~September 30~~,
		2014		2013
		December 31,		December 31,
(in thousands)		2014		2013
Derivatives not designated as hedging instruments
Commodity derivatives	Gain (loss) on commodity derivatives	$	~~269~~697	$	~~(384~~37	)
	Unrealized gain on commodity derivatives	$	—	$	64
		$	697	$	101

Unrealized gains and losses, at fair value, are included on the Company’s Consolidated Balance Sheets as current or non-current assets or liabilities based on the anticipated timing of cash settlements under the related contracts. Changes in the fair value of the Company’s commodity derivatives contracts are recorded in earnings as they occur and included in other income (expense) on the Company’s Consolidated Statements of Operations. The Company estimates the fair values of swap contracts based on the present value of the difference in exchange-quoted forward price curves and contractual settlement prices multiplied by notional quantities. The Company internally valued the option contracts using industry-standard option pricing models and observable market inputs. The Company uses its internal valuations to determine the fair values of the contracts that are reflected on its Consolidated Balance Sheets. Realized gains and losses are also included in other income (expense) on its Consolidated Statements of Operations.

	Income Statement Location	Six Months Ended,
		December 31,		December 31,
(in thousands)		2014		2013
Derivatives not designated as hedging instruments
Commodity derivatives	Realized loss on commodity derivatives	$	965	$	(51	)
	Unrealized gain on commodity derivatives		—		(231	)
		$	965	$	(282	)

Unrealized gains and losses, at fair value, are included on the Company’s Condensed Consolidated Balance Sheets as current or non-current assets or liabilities based on the anticipated timing of cash settlements under the related contracts. Changes in the fair value of the Company’s commodity derivatives contracts are recorded in earnings as they occur and included in other income (expense) on the Company’s Condensed Consolidated Statements of Operations. The Company estimates the fair values of swap contracts based on the present value of the difference in exchange-quoted forward price curves and contractual settlement prices multiplied by notional quantities. The Company internally valued the option contracts using industry-standard option pricing models and observable market inputs. The Company uses its internal valuations to determine the fair values of the contracts that are reflected on its Condensed Consolidated Balance Sheets. Realized gains and losses are also included in other income (expense) on the Company’s Condensed Consolidated Statements of Operations.

The Company is exposed to credit losses in the event of nonperformance by the counterparties on its commodity derivatives positions and has considered the exposure in its internal valuations. However, the Company does not anticipate nonperformance by the counterparties over the term of the commodity derivatives positions.

In connection with the closing of the Senior First Lien Secured Credit Agreement (as amended, the “Credit Agreement”) ~~with Cross Border~~, ~~Black Rock Capital, Inc. (“Black Rock”) and RMR Operating, LLC (collectively with~~ the Company, ~~the “Borrowers”) and Independent Bank, as Lender (the “Lender”), the Company~~ was required to enter into hedging agreements effectively hedging at least 50% of the oil volumes of the Company and its subsidiaries. At the same time, the Company entered into a Novation Agreement with BP Energy Company, LP (“BP Energy”) that transferred Cross Border’s then-existing swap agreements to the Company. Pursuant to an Inter-Borrower Agreement ~~among~~between the ~~Borrowers,~~Company and Cross Border, the Company allocates these swap agreements back to Cross Border and may allocate future hedging agreements related to Cross Border’s production to Cross Border. ~~See ‘Note 8. Debt-Credit Facility.”~~

7. Fair Value Measurements

Fair value measurements are based upon inputs that market participants use in pricing an asset or liability, which are classified into two categories: observable inputs and unobservable inputs. Observable inputs represent market data obtained from independent sources, whereas unobservable inputs reflect a company’s own market assumptions, which are used if observable inputs are not reasonably available without undue cost and effort. These two types of inputs are further prioritized into the following fair value input hierarchy:

●· Level 1 - quoted prices for identical assets or liabilities in active markets. · Level 2 - quoted prices for similar assets or 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 (e.g. interest rates) and inputs derived principally from or corroborated by observable market data by correlation or other means. · Level 3 - unobservable inputs for the asset or liability.

●	Level 2 - quoted prices for similar assets or 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 (e.g. interest rates) and inputs derived principally from or corroborated by observable market data by correlation or other means.
●	Level 3 - unobservable inputs for the asset or liability.

The fair value input hierarchy level to which an asset or liability measurement in its entirety falls is determined based on the lowest level input that is significant to the measurement in its entirety.

The following table summarizes the valuation of the Company’s financial assets and liabilities at ~~September~~December 3031, 2014 and June 30, 2014:

	Fair Value Measurements at Reporting Date Using
	Quoted Prices in Active Markets for Identical Assets or Liabilities (Level 1)		Significant or Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)			Fair Value at September 30, 2014
(in thousands)	Quoted Prices in Active Markets for Identical Assets or Liabilities (Level 1)		Significant or Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)			Fair Value at December 31, 2014
(in thousands)
Assets:
Commodity derivatives	$	—	$	~~189~~303	$	—		$	~~189~~303
Oil and gas properties impairment (non-recurring)		—		—		(36	)		(36	)
Oil and gas properties impairment (nonrecurring)		—		—		(29,054	)		(29,054	)
Total	$	—	$	~~189~~303	$	(3629,054	)	$	~~153~~(28,751	)
Liabilities:
Asset retirement obligations (non-recurring)	$	—	$	—	$	(5,~~748~~801	)	$	(5,~~748~~801	)
Environmental remediation liability		—		—		(2,057	)		(2,057	)
Total	$	—	$	—	$	(7,~~805~~858	)	$	(7,~~805~~858	)

	Fair Value Measurements at Reporting Date Using
	Quoted Prices in Active Markets for Identical Assets or Liabilities (Level 1)		Significant or Other Observable Inputs (Level 2)			Significant Unobservable Inputs (Level 3)			Fair Value at June 30, 2014
(in thousands)
Assets:
Commodity derivatives	$	—	$	37		$	—		$	37
Oil and gas properties impairment (non-recurring)		—		—			(487	)		(487	)
Total	$	—	$	37		$	(487	)	$	(450	)
Liabilities:
Asset retirement obligations (non-recurring)	$	—	$	—		$	(5,745	)	$	(5,745	)
Commodities derivative liability		—		(121	)		—			(121	)
Environmental remediation liability		—		—			(2,067	)		(2,067	)
Total	$	—	$	(121	)	$	(7,812	)	$	(7,933	)

The following is a summary of changes to fair value measurements using Level 3 inputs during the quarter ended September 30, 2014:


	Fair Value Measurements at Reporting Date Using
(in thousands)	Quoted Prices in Active Markets for Identical Assets or Liabilities (Level 1)		Significant or Other Observable Inputs (Level 2)			Significant Unobservable Inputs (Level 3)			Fair Value at June 30, 2014
Assets:
Commodity derivatives	$	—	$	37		$	—		$	37
Oil and gas properties impairment (nonrecurring)		—		—			(487	)		(487	)
Total	$	—	$	37		$	(487	)	$	(450	)

Liabilities:
Asset retirement obligations (non-recurring)	$	—	$	—		$	(5,745	)	$	(5,745	)
Commodity derivative		—		(121	)		—			(121	)
Environmental remediation liability		—		—			(2,067	)		(2,067	)
Total	$	—	$	(121	)	$	(7,812	)	$	(7,933	)

(in thousands)	Environmental Liability
Balance, June 30, 2014	$	(2,067	)
Settlement of liabilities		10
Balance, September 30, 2014	$	(2,057	)

8. Debt

As of the dates indicated, the Company’s debt consisted of the following:

	September 30,		June 30,
(in thousands)	December 31, 2014		June 30 2014
	2014		2014
Credit Facility	$	27,800	$	26,800
(in thousands)
Mandatorily redeemable preferred stock, net of discount of $1,367 and $1,561, respectively		4,995		4,801
Credit Facility	$	26,800	$	26,800
Total debt		32,795		31,601
Mandatorily redeemable preferred stock and accrued dividends, net of discount of $1,464 and $1,561, respectively		4,898		4,801
Less: short-term portion		27,800		—
Total debt		31,698		31,601
Long-term debt	$	4,995	$	31,601
Less: short-term portion		26,800		—
Long-term debt	$	4,898	$	31,601

Credit Facility

On February 5, 2013, the Company entered ~~into~~ into the Credit Agreement with Cross Border, Black Rock Capital, Inc., and RMR Operating, LLC (collectively with the Company, the “Borrowers”) and Independent Bank, as Lender (the “Lender”). The Credit Agreement provides for ana ~~up to $100.0 million~~ revolving ~~credit~~ credit facility (as amended, the “Credit Facility”) with a maturity date of February 5, 2016. The borrowing base under ~~the~~ the Credit Facility is determined at the discretion of the Lender based on, among other things, the Lender’s estimated value of the proved reserves attributable to the Borrowers’ oil and natural gas properties that have been mortgaged to the Lender, and is subject to regular redeterminations on September 30 and March 31 of each year, and interim redeterminations described in the Credit Agreement and potentially monthly commitment reductions, in each case which may reduce the amount of the borrowing base. As of ~~September~~December 3031, 2014, the borrowing base was $30.0 million.

A portion of the Credit Facility, in an aggregate amount not to exceed $2.0 million, may be used to issue letters of credit for the account of Borrowers. The Borrowers may be required to prepay the Credit Facility in the event of a borrowing base deficiency as a result of over-advances, sales of oil and gas properties or terminations of hedging transactions.

Amounts outstanding under the Credit Facility bear interest at a rate per annum equal to the greater of (x) the U.S. prime rate as published in The Wall Street Journal’s “Money Rates” table in effect from time to time and (y) 4.0% (4.0% at ~~September~~December 3031, 2014). Interest is payable monthly in arrears on the last day of each calendar month. Borrowings under the Credit Facility are secured by first priority liens on substantially all the property of each of the Borrowers and are unconditionally guaranteed by Doral West Corp. and Pure Energy Operating, Inc., each a subsidiary of Cross Border.

Under the Credit Agreement, the Borrowers are required to pay fees consisting of (i) an unused facility fee equal to 0.5% multiplied by the average daily unused commitment amount, payable quarterly in arrears until the commitment is terminated; (ii) a fronting fee payable on the date of issuance of each letter of credit and annually thereafter or on the date of any increase or extension thereof, equal to the greater of (a) 2.0% per annum multiplied by the face amount of such letter of credit or (b) $1,000; and (iii) an origination fee (x) of $200,000, and (y) payable on any date the commitment is increased, an additional facility fee equal to 1.0% multiplied by any increase of the commitment above the highest previously determined or redetermined commitment.

The Credit Agreement contains negative covenants that may limit the Borrowers’ ability to, among other things, incur liens, incur additional indebtedness, enter into mergers, sell assets, make investments and pay dividends. The Credit Agreement permits the payment of cash dividends on the Company’s 10.0% Series A Convertible Redeemable Preferred Stock (the “Series A Preferred Stock”) so long as the Company is not otherwise in default under the Credit Agreement and payment of such cash dividends would not cause the Company to be in default under the Credit Agreement.12

11The Credit Agreement contains negative covenants that may limit the Borrowers’ ability to, among other things, incur liens, incur additional indebtedness, enter into mergers, sell assets, make investments and pay dividends. The Credit Agreement permits the payment of cash dividends on the Company’s 10.0% Series A Cumulative Redeemable Preferred Stock (the “Series A Preferred Stock”) so long as the Company is not otherwise in default under the Credit Agreement and payment of such cash dividends would not cause the Company to be in default under the Credit Agreement.

The Credit Agreement also contains financial covenants, measured as of the last day of each fiscal quarter of Red Mountain, requiring the Borrowers to maintain a ratio of (i) the Borrowers’ and their consolidated subsidiaries’ consolidated current assets (inclusive of the unfunded commitment amount under the Credit Agreement) to consolidated current liabilities (exclusive of the current portion of long-term debt under the Credit Agreement) of at least 1.00 to 1.00; (ii) the Borrowers’ and their subsidiaries’ consolidated “Funded Debt” to consolidated EBITDAX (for the four fiscal quarter period then ended) of less than 3.50 to 1.00; and (iii) the Borrowers’ and their subsidiaries’ consolidated EBITDAX less paid and accrued dividends on the Series A Preferred Stock to interest expenses (each for the four fiscal quarter period then ended) of at least 3.00 to 1.00. Funded Debt is defined in the Credit Agreement as the sum of all debt for borrowed money, whether as a direct or reimbursement obligor, but excludes shares of Series A Preferred Stock. EBITDAX is defined in the Credit Agreement as (a) consolidated net income plus (b) (i) interest expense, (ii) income taxes, (iii) depreciation, (iv) depletion and amortization expenses, (v) dry hole and exploration expenses, (vi) non-cash losses or charges on any hedge agreements resulting from derivative accounting, (vii) extraordinary or non-recurring losses, (viii) expenses that could be capitalized under GAAP but by election of Borrowers are being expensed for such period under GAAP, (ix) costs associated with intangible drilling costs, (x) other non-cash charges, (xi) one-time expenses associated with transactions associated with (b)(i) through (iv), minus (c)(i) non-cash income on any hedge agreements resulting from FASB Statement 133, (ii) extraordinary or non-recurring income, and (iii) other non-cash income.

Amounts outstanding under the Credit Facility may be accelerated and become immediately due and payable upon specified events of default of Borrowers, including, among other things, a default in the payment of principal, interest or other amounts due under the Credit Facility, certain loan documents or hydrocarbon hedge agreements, failure to perform or observe covenants under the Credit Facility, a material inaccuracy of a representation or warranty, a default with regard to certain loan documents which remains unremedied for a period of 30 days following notice, a default in the payment of other indebtedness of the Borrowers of $200,000 or more, bankruptcy or insolvency, certain changes in control, failure of the Lender’s security interest in any portion of the collateral with a value greater than $500,000, cessation of any security document to be in full force and effect, or Alan Barksdale ceasing to be Red Mountain’s Chief Executive Officer or Chairman of Cross Border and not being replaced with an officer acceptable to the Lender within 30 days.

Pursuant to the Credit Agreement, at least ~~one~~ one of the Borrowers is required to have acceptable hydrocarbon hedge agreements in place at all times effectively hedging at least 50% of the oil volumes of the Borrowers., ~~Red~~derived ~~Mountain~~from ~~has~~the ~~outstanding~~most ~~hedge~~recent ~~agreements~~third ~~with~~party ~~various~~engineering ~~counterparties~~report ~~hedging~~received aby ~~portion~~Lender ~~of the future oil production of~~covering ~~the~~a ~~Borrowers. However, these hedge agreements did not comply with the volume and time~~ period ~~requirements~~ of ~~the~~not ~~Credit~~less ~~Agreement as~~than ofeighteen ~~September~~(18) ~~30,~~consecutive ~~2014~~months.

As of ~~September~~December 3031, 2014, the Borrowers ~~had~~ had collectively borrowed $2627.8 million and had no availability ~~of $3.2 million~~ under the Credit Facility. ~~On October 14, 2014, the Company borrowed an additional $1.0 million under the Credit Facility.~~ The Company was not in compliance with all of the financial covenants and the hedge agreement covenant under the Credit Facility described above at ~~September~~December 3031, 2014, ~~which~~ which constitutes an event of default under the Credit Facility, and the Lender has the right to accelerate all amounts outstanding under the Credit Facility upon notice to the Borrowers. As a result, the Company has (i) recorded the full amount of its outstanding borrowings under the Credit Facility as a current liability on its Consolidated Balance Sheet as of ~~September 30~~December 31, 2014 and (ii) included a “going concern” note in its consolidated financial staetments.

Mandatorily Redeemable Preferred Stock

The Company’s Series A Preferred Stock is mandatorily redeemable and is not convertible into shares of the Company’s common stock. The Company classifies the Series A Preferred Stock as a long-term liability, and the Company records dividends paid or accrued as interest expense in the Company’s Condensed Consolidated Statement of Operations. Because the Company is in default under the Credit Facility, as described above, we cannot pay dividends on the Series A Preferred Stock.

In August 2013, the Company closed ~~offerings~~ offerings of ~~376~~476,~~685~~687 Units (the “Units”), including 100,002 Units sold in cancellation of $2.3 million in debt under convertible notes payable to Hohenplan Privatstiftung and SST Advisors, Inc., raising net ~~cash~~ proceeds of $7.1 million. Each Unit consisted of one share of Series A Preferred Stock and one warrant to purchase up to 2.5 shares of common stock at a price of $22.50 per Unit. The warrants are exercisable until the earlier of (i) August 2016 or (ii) the first trading day that is at least 30 days after the date that the Company has provided notice to the holders of the warrants by filing a Current Report on Form 8-K stating that the ~~common~~ common stock has (A) achieved a 20 trading day volume weighted average price of $15.00 per share or more and (B) traded, in the aggregate, 300,000 shares or more over the same 20 consecutive trading days for which the 20 trading day volume weighted ~~average~~ average price was calculated; provided, that clause (ii) shall only be applicable so long as a warrant is exercisable for shares of common stock. The warrants have an exercise price of $10.00 per share. The warrants issued with the Series A Preferred Stock were valued at $2.4 million. The value of the warrants is treated as a discount to the Series A Preferred Stock and will be accreted over the life of the mandatorily redeemable preferred stock. Management determined the fair value using a probability weighted Black-Scholes option model with a volatility based on the historical closing price of common stock of industry peers and the closing price of the Company’s common stock on the OTCBB on the date of issuance. The volatility and remaining term was approximately 55% and three years, respectively.

12 The Series A Preferred Stock is mandatorily redeemable on July 15, 2018 at $25.00 per share, plus accrued and unpaid dividends to the redemption date, for a total redeemable value of $11.9 million at the time of issuance. The difference between the $11.9 million redeemable value and the $10.8 million of gross proceeds and canceled debt is treated as a discount and will be accreted over the life of the Series A Preferred Stock. As of December 31, 2014, the Company had 254,463 shares of Series A Preferred Stock outstanding.

~~The~~For ~~Series~~the Athree ~~Preferred~~and ~~Stock~~six ismonths ~~mandatorily redeemable~~ended ~~on July 15~~December 31, ~~2018 at $25.00 per share~~2014, ~~plus accrued and unpaid dividends to~~ the ~~redemption~~Company ~~date,~~recognized ~~for a~~ total ~~redeemable value~~interest ofexpense ~~$11.9 million at the time~~ of ~~issuance. The difference between the~~ $110.93 million ~~redeemable value~~ and ~~the~~ $100.86 million of, ~~gross~~respectively, ~~proceeds~~related ~~and~~to ~~canceled debt is treated as a discount and will be accreted over~~ the ~~life of the~~ Series A Preferred Stock~~. Effective as of April 1~~, ~~2014,~~which ~~the~~includes ~~Company~~accretion ~~agreed~~of todiscount ~~exchange~~and ~~222,224~~amortization ~~outstanding shares~~ of ~~its Series A Preferred Stock for the~~ issuance costs of $0.1~~,388,898~~ ~~shares~~million ofand ~~common stock~~$0.2 ~~After~~million ~~the~~for ~~exchange,~~ the ~~Company had 254,463 shares of Series A Preferred Stock outstanding~~ ~~with~~three anand ~~aggregate~~six ~~redemption~~months ~~amount~~ended ofDecember ~~$6.4 million as of September 30~~31, 2014, respectively.

For the three months ended September 30, 2014, the Company recognized total interest expense of $0.3 million related to the Series A Preferred Stock, which includes accretion of discount and issuance cost of $0.1 million for the three months ended September 30, 2014.

Schedule of Future Debt Payments

The following is a schedule by fiscal year of of future principal payments required under the Company’s outstanding debt as of ~~September~~December 3031, 2014:

(in thousands)
Fiscal Years Ending June 30,
2015	$	~~26,800~~$	—
2016		—	27,800
2017		—	—
2018		—	—
2019		~~6,362~~	6,362
Total		~~33,162~~	34,162
Discount		~~(1,464~~	)(1,367	)
Total, net value	$	~~31,698~~$	32,795

1314

9. Earnings Per Share

The Company reports basic earnings per common share, which excludes the effect of potentially dilutive securities, and diluted earnings per common share, which includes the effect of all potentially dilutive securities unless their impact is anti-dilutive. The following are reconciliations of the numerators and denominators of basic and diluted earnings per share:

	Three Months Ended September 30,
	Three Months Ended,						Six Months Ended,
	2014				2013
(dollars in thousands, except per share amounts)	December 31, 2014			December 31, 2013			December 31, 2014			December 31, 2013
(dollars in thousands, except per share amounts)
Net loss (numerator):
Net loss (numerator):
Net loss – basic	$	(31,519	)	$	(2,205	)	$	(34,411	)	$	(3,480	)
Net loss – basic	$	(2,892	)		$	(1,129	)
Weighted average shares (denominator):
Weighted average shares (denominator):
Weighted average shares – basic		14,857			13,372			14,857			13,147
Weighted average shares – basic		14,857				12,922
Dilution effect of share-based compensation, treasury method(1)		—			—			—			—
Dilution effect of share-based compensation, treasury method(1)		—				—
Weighted average shares – diluted		14,857			13,372			14,857			13,147
Weighted average shares – diluted		14,857				12,922
Loss per share:
Loss per share:
Basic	$	(2.12)		$	(0.16)		$	(2.32)		$	(0.26	)
Basic	$	(0.19	)		$	(0.10	)
Diluted	$	(2.12)		$	(0.16)		$	(2.32)		$	(0.26	)
Diluted	$	(0.19	)		$	(0.10	)

(1) Approximately 1,349,051 and 1,653,559 shares of common stock underlying warrants to purchase shares of the Company’s common stock were excluded from this calculation because they were anti-dilutive during the periods ended ~~September~~December 3031, 2014 and 2013, respectively.

10. Commitments and Contingencies

Litigation

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. and Everett Willard Gray II. Mr. Bloodworth alleges that Mr. Gray, as CEO of Cross Border, made false representations which induced Mr. Bloodworth to enter into an employment contract that was subsequently breached by Cross Border. The claims that Mr. Bloodworth has alleged are: breach of his employment agreement with Doral West Corp, 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 Cross Border deny that Mr. Bloodworth’s claims have any merit.

Cross Border was previously party to an an engagement letter, dated February 7, 2012 (the “Engagement Letter”) with KeyBanc Capital Markets Inc. (“KeyBanc”) pursuant to which KeyBanc was to act as exclusive financial advisor to Cross Border’s board of directors in connection with a possible “Transaction” (as defined in the Engagement Letter). The Engagement Letter was formally terminated by Cross Border on August 21, 2012. The Engagement Letter provided that KeyBanc would be entitled to a fee upon consummation of a Transaction within a certain period of time following termination of the Engagement Letter. On May 16, 2013, KeyBanc delivered an invoice to Cross Border representing a fee and out-of-pocket expenses purportedly owed by Cross Border to KeyBanc as a result of the consummation of a purported Transaction that KeyBanc asserts had been consummated within the required time period. Cross Border disputed that any Transaction was consummated and that KeyBanc was entitled to any fees or out-of-pocket expenses. Cross Border filed a complaint seeking (i) a declaration that it was not liable to KeyBanc for any amounts in connection with the Engagement Letter, (ii) attorneys’ fees, and (iii) costs of suit. KeyBanc filed a counterclaim seeking (i) compensatory damages, (ii) interest, (iii) expenses and ~~court~~ court costs, and (iv) reasonable and necessary attorneys’ fees. The matter was originally filed in the 44th Judicial District Court for the State of Texas, Dallas County but was subsequently removed to the United States District Court for the Northern District of Texas, Dallas Division. On August 26, 2014, Cross Border entered into a settlement agreement with KeyBanc, settling a lawsuit between the parties. In connection with the settlement, Cross Border agreed to pay KeyBanc $900,000 in three equal installments of $300,000 each on or before August 28, 2014, October 31, 2014 and December 31, 2014, and the parties agreed to mutual releases of liability related to the Engagement Letter. The Company fully accrued this amount at June 30, 2014. ~~The Company paid the first installment and the remaining installments are recorded in accrued expenses on the Company’s Consolidated Balance Sheets at September 30, 2014.~~

1415

In addition to the foregoing, in the ordinary course of business, the Company is periodically a party to various litigation matters that it does not believe will have a material adverse effect on its results of operations or financial condition.

Environmental ~~Issues~~issues

The Company is subject to federal and state laws and regulations relating to the protection of the environment. Environmental risk is inherent in all 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.

As of ~~September~~December 3031, 2014, the Company had approximately $2.1 million in environmental remediation liabilities related to Cross Border’s operated Tom Tom and Tomahawk fields located in Chaves and Roosevelt counties in New Mexico. In February 2013, the Bureau of Land Management (“BLM”) accepted Cross Border’s remediation plan for the Tom Tom and Tomahawk fields. Cross Border is working in conjunction with the BLM to initiate remediation on a site-by-site basis. This is management’s best estimate of the costs of remediation and restoration with respect to these environmental matters, although the ultimate cost could differ materially. Inherent uncertainties exist in these estimates due to unknown conditions, changing governmental regulation, and legal standards regarding liability, and emerging remediation technologies for handling site remediation and restoration. Cross Border has incurred approximately $43,000 in costs and expects to incur the remaining expenditures during the Company’s fiscal year ending June 30, ~~2015~~2016.

Leases

As of ~~September~~December 3031, 2014, the Company ~~rented~~ rented various office spaces in Dallas, Texas; Midland, Texas; and Lafayette, Louisiana under non-cancelable lease agreements. In the aggregate, these leases cover approximately 16,884 square feet at a cost of approximately $24,000 per month and have remaining lease terms ~~ranging~~of ~~from~~21 2 months ~~to 24 months~~. The following is a schedule by year of future minimum rental payments required under these lease arrangements as of ~~September~~December 3031, 2014:

(in thousands)
Fiscal Years Ending June 30,
2015	$	~~147~~152
2016		181
2017		45
2018		—
Total	$	~~373~~378

Rent expense under the Company’s lease arrangements amounted to approximately $7460,000 and $6964,000 for the three months ended ~~September~~December 3031, 2014 and December 31, 2013, respectively. Rent expense under the Company’s lease arrangements amounted to approximately $125,184 and $133,000 for the six months ended December 31, 2014 and December 31, 2013, respectively.

11. Related Party Transactions

Enerstar Resources O&G, LLC (“Enerstar”), a company owned by Tommy Folsom, the former Executive Vice President and Director of Exploration and Production for RMR Operating, LLC, a subsidiary of the Company, and formerly the Executive Vice President and Director of Exploration and Production for the Company, owns an overriding royalty interest in the Company’s Madera Prospect. During each of the three and six months ended December ~~September 30~~31, 2014 ~~and 2013,~~ the Company paid royalties of approximately $74,~~000~~400 ~~and $3,000, respectively,~~ to Enerstar.

1516

12. Subsequent Events

Hedge Agreements

On January 21, 2015, the Company entered into the following commodity derivative contracts:


Commodity and Time Period	Contract Type	Volume Transacted	Contract Price
Crude Oil
May 1, 2015—December 31, 2015	Put	5,500-7,000 Bbls/month	$	50.00/Bbl
January 1, 2016—June 30, 2016	Put	5,000-5,500 Bbls/month	$	58.00/Bbl

Third Amendment to Credit Agreement

On March 11, 2015, the Borrowers entered into an amendment and waiver (the “Third Amendment”) to the Credit Agreement with the Lender. Each of Cross Border, Black Rock and RMR Operating are subsidiaries of the Company. Pursuant to the Third Amendment, (i) Lender waived any default or right to exercise any remedy as a result of the failure by the Borrowers to be in compliance with the requirements of Section 6.18 of the Credit Agreement with respect to the permitted ratio of consolidated current assets to consolidated current liabilities of Borrowers for the fiscal quarter ended September 30, 2014; and (ii) the borrowing base was decreased from $30 million to $27.8 million,effective as of March 1, 2015, and the commitment amount was decreased to $27.8 million, subject to monthly commitment reductions of $350,000 beginning March 1, 2015.

Purchase and Sale Agreement

On April 21, 2015, RMR Operating, Black Rock, RMR KS Holdings, LLC (“RMR KS”) and Cross Border (together with RMR Operating, Black Rock and RMR KS, the “Operating Subsidiaries”) entered into a purchase and sale agreement (the “PSA”) with Black Shale Minerals, LLC (“Buyer”). Each of the Operating Subsidiaries is a subsidiary of the Company.

Pursuant to the PSA, the Company, through the Operating Subsidiaries, sold, assigned, transferred and conveyed to Buyer, effective as of April 1, 2015, fifty percent (50%) of its right, title, and interest in and to certain oil and natural gas assets and properties (the “Assets”), including its oil and natural gas leasehold interests, wells, contracts, and oil and natural gas produced after April 1, 2015. The aggregate purchase price for the Assets under the PSA was $25.0 million, subject to certain adjustments, including post-closing adjustments for any title or environmental benefits or title or environmental defects resulting from Buyer’s title and environmental reviews.

The PSA contains customary representations, warranties and covenants. Pursuant to the PSA, the Company and Buyer have agreed to indemnify each other, their respective affiliates and their respective employees, officers, directors, managers, shareholders, members, partners, or representatives from and against all losses that such indemnified parties incur arising from any breach of representations, warranties or covenants in the PSA and certain other matters.

Fourth Amendment to the Credit Agreement

In conjunction with the PSA, on April 21, 2015, the Borrowers entered into an amendment (the “Fourth Amendment”) to the Credit Agreement with the Lender. Pursuant to the Fourth Amendment, the borrowing base was decreased from $27.8 million to $12.4 million, effective as of April 21, 2015, and the commitment amount was decreased to $12.4 million. In addition, the monthly commitment reduction amount was set to $0 as of April 1, 2015.

Fifth Amendment to the Credit Agreement

Effective June 30, 2015, the Borrowers entered into an amendment and waiver (the “Fifth Amendment”) to the Credit Agreement with the Lender. Pursuant to the Fifth Amendment, the borrowing base was set at $12.4 million, and the initial monthly commitment reduction was set at $125,000 beginning on July 1, 2015. In addition, the Lender waived any default, event of default or right to exercise any remedy as a result of the failure by the Borrowers to be in compliance with (i) the requirements of Section 6.18 of the Credit Agreement with respect to the permitted ratio of consolidated current assets to consolidated current liabilities of Borrowers for the fiscal quarter ended December 31, 2014; and (ii) the requirements of Section 6.21 of the Credit Agreement with respect to the trade payables or other accounts payable of Borrowers that may be past due for more than 90 days for the fiscal quarter ended December 31, 2014 and the fiscal quarter ended March 31, 2015.

Lease and Lease Amendment

On July 31, 2015, the Company entered into an amendment and consent to assignment of lease pursuant to which the Company assigned its lease for its office space in Dallas, Texas, to a new tenant, effective as of November 1, 2015. The Company and the new tenant will be jointly and severally liable under the lease through October 1, 2016. In addition, the Company entered into a lease agreement for approximately 4100 square feet of new office space, for approximately $2700 per month and a term of three years beginning on September 1, 2015.

Unwinding of Hedge Agreements

On August 19, 2015, the Company unwound a portion of its commodity derivative positions for net proceeds of $18,600.

Deregistration

On November 13, 2015, the Company’s Board of Directors voted to voluntarily deregister the Company’s common stock, Series A Preferred Stock and warrants under the Exchange Act and become a non-reporting company. In connection therewith, the Board of Directors approved the filing with the SEC of a Form 15 to voluntarily deregister the Company’s securities under Section 12(g) of the Exchange Act and suspend its reporting obligations under Section 15(d) of the Exchange Act. The Company expects to file the Form 15 on or about November 13, 2015. The Company expects that its obligations to file periodic reports, such as Annual Reports on Form 10-K, Quarterly Reports on Form 10-Q and Current Reports on Form 8-K, will be suspended immediately upon the filing of the Form 15 with the SEC, and its proxy statement, Section 16 and other Section 12(g) reporting responsibilities will terminate effective 90 days after the filing of the Form 15. The Company is eligible to deregister under the Exchange Act because its common stock, Series A Preferred Stock and warrants are each held by fewer than 300 shareholders of record.

Arbitration Claim

On August 27, 2015, the Company received a demand for arbitration with the Dallas, Texas office of the American Arbitration Association (“AAA”) that was filed by a former RMR employee, Tommy Folsom. The arbitration demand asserts claims for breach of contract and defamation and identifies the total claim amount as $100,000 and further seeks unspecified attorney’s fees, interest, arbitration costs, and punitive/exemplary damages. The Company disputes the allegations in the arbitration proceedings made by Mr. Folsom. The parties are engaged in settlement negotiations.

Item 2.

Management’s Discussion and Analysis of Financial Condition and Results of Operations

Unless the context otherwise requires, ~~all~~ all references to ~~“Red Mountain,”~~ the “Company,” “we,” “our” and “us” refer to (i) Red Mountain Resources, Inc., a Texas corporation (“Red Mountain”), (ii) Red Mountain’s wholly owned subsidiaries, including Black Rock Capital, Inc. (“Black Rock”) and RMR Operating, LLC (“RMR Operating”), and (iii) subsequent to January 28, 2013, Cross Border Resources, Inc. (“Cross Border”). As of ~~September~~December 3031, 2014, we owned 83% of the outstanding common stock of Cross Border. Acreage, reserves and production information presented subsequent to January 28, 2013 includes acreage, reserves and production represented by the 17% of Cross Border’s common stock not owned by us.

Overview

We are a Dallas-based ~~growth-oriented energy~~ company ~~engaged~~with ~~in the acquisition, development and exploration of~~ oil and natural gas properties in ~~established basins with demonstrable prolific producing zones. Currently, we have established acreage positions and production in~~ the Permian Basin of West Texas and Southeast New Mexico, ~~and~~ the onshore Gulf Coast of Texas. ~~Additionally, we have an established~~ and ~~growing acreage position in~~ Kansas.

WeIn ~~plan~~light toof ~~grow~~the ~~production~~Company's ~~and~~limited ~~reserves~~activities, bythe ~~acquiring,~~Company has determined that it is advisable to terminate the registration ~~exploring~~of ~~and~~its ~~developing~~securities anunder ~~inventory~~the Securities Exchange Act of ~~long-life~~1934, ~~low~~as ~~risk~~amended ~~drilling~~(the ~~opportunities~~"Exchange Act"). The Company anticipates filing a Form 15 with ~~attractive~~the ~~rates~~Securities ofand ~~return~~Exchange Commission ("SEC") to effect the deregistration on or about November 13, 2015. After ~~Our~~careful ~~focus~~consideration, the Board of Directors decided to deregister based on its belief that the savings the Company iswill achieve as a result of deregistration, particularly on ~~opportunities~~costs inrelated to the preparation and ~~around~~filing ~~producing~~of ~~oil~~SEC reports and compliance ~~natural~~with ~~gas~~Sarbanes-Oxley ~~properties~~obligations, ~~where~~will webenefit ~~can~~shareholders, ~~enhance~~and ~~production~~such ~~and~~benefits ~~reserves~~will ~~through application~~outweigh any advantages of ~~newer~~continuing as ~~drilling~~an ~~and~~SEC ~~completion~~reporting ~~techniques~~company. Upon the filing of the Form 15, ~~infill~~the ~~drilling~~Company's ~~targeting~~obligation ~~untapped~~to ~~but~~file ~~known~~periodic ~~productive~~and ~~hydrocarbon~~current ~~strata,~~reports with the SEC, including Forms 10-K, 10-Q, and ~~enhanced~~8-K, ~~oil~~will ~~recovery~~be ~~applications~~suspended.

AsIn light of ~~November~~the ~~17,~~Company’s ~~2014~~limited activities, wethe ~~owned~~Company ~~interests~~has determined that it is advisable to terminate the registration of its securities under the Securities inExchange ~~887~~Act of 1934,~~501~~ ~~gross~~as amended (~~310,392~~the ~~net~~“Exchange Act”). ~~mineral~~The Company anticipates filing a Form 15 with the Securities and ~~lease~~Exchange ~~acres~~Commission in(“SEC”) ~~New~~to ~~Mexico~~effect the deregistration on or about November 13, ~~Texas~~2015. ~~and~~After ~~Kansas~~careful consideration, the Board of ~~which~~Directors ~~336,331~~decided ~~gross~~to ~~(30,926~~deregister ~~net)~~based ~~acres are~~on ~~within~~its ~~the~~belief ~~Permian~~that ~~Basin.~~the Wesavings ~~have~~the ~~successfully~~Company ~~leased~~will ~~9,868~~achieve ~~net~~as ~~acres~~a inresult ~~Kansas~~of ~~located~~deregistration, particularly on costs related to the ~~Central~~preparation ~~Kansas~~and ~~Uplift,~~filing of SEC reports and ~~we also~~compliance ~~owned~~with ~~interests~~Sarbanes-Oxley inobligations, ~~over~~will benefit 1shareholders,~~405~~ ~~net~~and ~~acres~~such ~~located~~benefits onwill outweigh any advantages of continuing as an SEC reporting company. Upon the ~~Villarreal,~~filing of ~~Frost~~the ~~Bank,~~Form ~~Resendez~~15, ~~Peal~~the ~~Ranch~~Company’s obligation to file periodic and Lacurrent ~~Duquesa~~reports ~~Prospects in~~with the ~~Gulf~~SEC, ~~Coast~~including ofForms ~~Texas~~10-K, 10-Q, and 8-K, will be suspended.

As of September 30, 2014, we had $26.8 million of borrowings under our Senior First Lien Secured Credit Agreement (as amended, the “Credit Agreement”) with Cross Border, Black Rock and RMR Operating (collectively with the Company, the “Borrowers”) and Independent Bank, as Lender (the “Lender”), which provides for an up to $100.0 million revolving credit facility (as amended, the “Credit Facility”). This indebtedness is secured by substantially all of our assets and the assets of our subsidiaries. The Credit Agreement contains covenants which require us to maintain compliance with certain financial ratios, aging of accounts payable and maintenance of agreements that hedge the price of oil. As of September 30, 2014, we were not in compliance with certain of these covenants and, as a result, the Lender has the right to accelerate all amounts outstanding under the Credit Facility upon notice to the Borrowers. Due to the noncompliance, we have (i) reclassified the full amount of the outstanding borrowings under the Credit Facility from a long-term liability to a short-term liability on our Consolidated Balance Sheets as of September 30, 2014 and (ii) included a “going concern” note in our consolidated financial statements. We are in discussions with the Lender regarding either a waiver of the non-compliance or an amendment to the Credit Agreement to cure the non-compliance. While we anticipate obtaining a waiver from the Lender, we cannot provide any assurance that these negotiations will be successful.

Fiscal 2015 First Quarter Operational Update

Net production sold for the quarter ended September 30, 2014 was 100,000 barrels of oil equivalent (“Boe”), or 1,087 Boe per day (“Boe/d”), based on actual calendar days during the period, inclusive of 9.6 Mboe, or 105 Boe/d, of prior period adjustments.

During the three months ended September 30, 2014, we completed two wells (0.2 net) at our Turkey Track Prospect, worked over three wells (2.8 net) in the Tom Tom Area, and drilled five gross (five net) wells in Kansas. We recently commenced the completion of the Madera 25 Federal 2H well.

During the quarter, we completed the Zircon 2 B1EH State 2H well, our first well targeting the 1st Bone Spring reservoir at our Turkey Track Prospect. It was completed in July 2014 and achieved a maximum 24-hour production rate of 632 Boe/d (of which 87% was oil) and a 10-day average production rate of 549 Boe/d (of which 81% was oil). We own an approximately 13% working interest and 9% net revenue interest in this well. The Bradley 31 B2DA Federal Com 1H well, a horizontal well targeting the 2nd Bone Spring, was completed in September 2014 and achieved a maximum 24-hour production rate of 889 Boe/d (of which 88% was oil) and a 10-day average production rate of 790 Boe/d (of which 88% was oil). We own an approximately 7% working interest and 5% net revenue interest in this well. In October 2014, we spud the Perla Verde 31 State 2H, a horizontal well targeting the 3rd Bone Spring, in which we own an approximately 6.3% working interest and 4.7% net revenue interest. In November 2014, we spud the Scooter Federal Com 1H and the Zircon 12/7 B2JK Federal Com 1H horizontal wells targeting the 2nd Bone Spring, in which we own an approximately 0.8% working interest and 0.6% net revenue interest and an approximately 16% working interest and 12% net revenue interest, respectively. All three of these wells are non-operated wells and are currently drilling.

In the Tom Tom Area, we continued our workover program completing work on three wells in the field during the three months ended September 30, 2014. In the first of these, on the Strange Federal 1 well, we added perforations, treated the well with acid, and fracture stimulated the well, increasing its production from less than 1 Bbl/d of oil to approximately 6 Bbl/d oil. We own a 100% working interest and an approximately 75% net revenue interest in the well. We also completed work on the Wattam Federal 4 and Hahn Federal 7 wells during the first quarter, adding new perforations to the Hahn Federal 7 well and treating both wells with acid. We are awaiting flowback results on both of these workovers. We own a 100% working interest and 77% net revenue interest in the Wattam Federal 4 well, and an approximately 78% working interest and 64% net revenue interest in the Hahn Federal 7 well. In October 2014, we commenced work on the Loveless LQ State 2 well, a well in the Tom Tom Area in which we own an approximately 65% working interest and 57% net revenue interest. We added new perforations, treated the well with acid, and are currently awaiting flowback results.

During the quarter, we also drilled five wells in Rush County, Kansas, targeting the Arbuckle, Basal Penn, Reagan, and Lansing-Kansas City formations. Three of these wells, the Besperat 1, Koriel 1, and Elder 1 wells, did not encounter commercial hydrocarbons and were plugged and abandoned. The Stalcup 1 well was completed in the Arbuckle formation in September 2014 and is currently producing. The well has averaged approximately 8 Bbl/d of oil since its completion. As of September 30, 2014, the Gisick 1 well was drilled and awaiting completion. We own a 100% working interest and a net revenue interest ranging from 83% to 88% in these five wells.

Critical Accounting Policies and Estimates

Our discussion and analysis of our financial condition and results of operations is based upon our condensed consolidated financial statements, which have been prepared in accordance with generally accepted accounting principles in the United States (“GAAP”). The preparation of these condensed consolidated financial statements requires management to make estimates and judgments that affect the reported amounts of assets, liabilities, revenue and expenses and related disclosures. Our significant accounting policies are described in “Note 23—~~Significant~~Summary of Significant Accounting Policies” to our audited consolidated financial statements included in our Annual Report on Form 10-K for the fiscal year ended June 30, 2014 and are of particular importance to the portrayal of our financial position and results of operations and require the application of significant judgment by management. These estimates are based on historical experience, ~~information~~ information received from third parties, and on various other assumptions that are believed to be reasonable under the circumstances, the results of which form the basis for making judgments about the carrying values of assets and liabilities that are not readily ~~apparent~~ apparent from other sources. Actual results may differ from these estimates under different assumptions or conditions. There have been no changes to the significant accounting policies disclosed in our Annual Report on Form 10-K for the fiscal year ended June 30, 2014.

Results of Operations

~~The~~Three ~~following~~Months ~~table~~Ended ~~sets~~December ~~forth summary information regarding our oil and natural gas sales~~31, ~~net~~2014 ~~production~~Compared ~~sold,~~to ~~average sales prices and production costs and expenses for the three~~Three ~~months~~Months ~~ended~~Ended ~~September~~December 3031, ~~2014 and~~ 2013.

	Three Months Ended
	September 30, 2014		September 30, 2013
(dollars in thousands, except per unit prices)
Revenue
Oil and natural gas sales	$	5,272	$	5,774
Net Production sold
Oil (Bbl)		48,896		43,649
Natural gas (Mcf)		224,146		241,017
Natural gas liquids (Bbl)		13,728		6,293
Total (Boe)		99,982		90,112
Total (Boe/d) (1)		1,087		979
Average sales prices
Oil ($/Bbl)	$	83.61	$	102.46
Natural gas ($/Mcf)		3.17		4.52
Natural gas liquids ($/Bbl)		32.17		28.57
Total average price ($/Boe)	$	52.41	$	63.72
Costs and expenses (per Boe)
Exploration expense	$	2.50	$	1.12
Dry hole expense		5.33		—
Production taxes		4.19		6.72
Lease operating expenses		11.56		8.29
Natural gas transportation and marketing expenses		0.98		0.42
Depreciation, depletion, amortization and impairment		24.09		23.20
Accretion of discount on asset retirement obligation		0.34		0.75
General and administrative expense		26.89		21.57

Revenues

~~(1)~~Oil ~~Boe/d~~and isNatural ~~calculated~~Gas ~~based~~Sales. During the onthree ~~actual~~months ~~calendar~~ended ~~days~~December ~~during~~31, 2014, we had oil and natural gas sales of $3.4 million, as compared to $4.5 million during the three months ended December 31, 2013. The decrease in oil and natural gas sales was primarily attributable to lower commodity ~~period~~prices.

Revenues and Production

Oil and Natural Gas Production. During the three months ended September 30, 2014, we had net production sold of 99,982 Boe, compared to net production sold of 90,112 Boe during the three months ended September 30, 2013. The increase in net production sold was primarily attributable to production from new wells and from prior period adjustments, partially offset by the natural decline of producing properties. For the three months ended September 30, 2014, 48.9% of our production was oil, 37.4% was natural gas and 13.7% was natural gas liquids, compared to 48.4% oil, 44.6% natural gas and 7.0% natural gas liquids for the three months ended September 30, 2013.

Oil and Natural Gas Sales. During the three months ended September 30, 2014, we had oil and natural gas sales of $5.3 million, as compared to $5.8 million during the three months ended September 30, 2013. The decrease in oil and natural gas sales was primarily attributable to the decrease in commodity prices.

Costs and Expenses

Exploration Expense. Exploration ~~expense~~ expense was $0.35 million for the three months ended ~~September~~December 3031, 2014, as compared to $0.13 million for the three months ended ~~September~~December 3031, 2013. The increase in exploration expense was ~~primarily~~ attributable to ~~increased~~ seismic ~~activity~~costs ~~during~~and ~~the~~dry ~~three~~hole ~~months ended September 30, 2014~~expense.

~~Dry~~Production ~~Hole Expense~~Taxes. ~~Dry hole expense~~ Production ~~was~~taxes were $0.52 million for the three months ended ~~September~~December 3031, 2014, as compared to $0.6 million for the three months ended ~~September~~ 30December 31, 2013. The ~~increase~~decrease in ~~dry~~production ~~hole~~taxes ~~expense~~ was ~~primarily~~ attributable to ~~three~~lower ~~Kansas~~realized ~~wells~~sales ~~that~~prices ~~did~~as ~~not~~a ~~encounter commercial~~result ~~hydrocarbons~~of ~~and~~lower ~~were~~commodity ~~plugged and abandoned~~prices.

~~Production~~Lease ~~Taxes.~~Operating ~~Production taxes were $0~~Expenses.~~4 million for~~ During the three months ended ~~September~~December 3031, 2014, we incurred lease operating expenses of $1.1 million, as compared to $0.67 million ~~for~~ during the three months ended ~~September~~December 3031, 2013. The increase in lease operating expenses was attributable to costs related to a new Madera well and additional workover expenses.

Lease Operating Expenses. During the three months ended September 30, 2014, we incurred lease operating expenses of $1.2 million, as compared to $0.7 million during the three months ended September 30, 2013. The increase in lease operating expenses was attributable to new wells and workover expense that was not incurred in the prior year.19

Natural Gas Transportation and Marketing Expenses. For the three months ended ~~September~~December 3031, 2014, natural gas transportation and marketing expenses was $9839,000, as as compared to $3837,000 for the three months ended ~~September~~December 3031, 2013.

Depreciation, Depletion, Amortization ~~and~~ and Impairment. For the three months ended ~~September~~December 3031, 2014, depreciation, depletion, amortization and impairment was $230.46 million, as compared to $2.12 million for the three months ended ~~September~~December 3031, 2013. The increase in depreciation, depletion, ~~amortization~~ amortization and impairment was attributable to ~~additional~~impairment ~~wells~~of in our ~~Madera~~oil ~~field~~and gas assets resulting from significantly lower commodity prices.

General and Administrative Expense. General and administrative expense was $21.74 million for the three months ended ~~September~~December 3031, 2014, as compared to $1.9 million for the ~~three~~ three months ended ~~September~~December 3031, 2013. The ~~increase~~decrease in general and administrative expense was ~~due~~ primarily attributable to ~~approximately~~lower ~~$1.0~~personnel ~~million~~costs, ofprofessional ~~non-recurring~~fees ~~expenses related to our cancelled preferred stock offering in September 2014~~ and ~~increased~~litigation ~~professional fees associated with our internal control improvements~~expense.

Other Expense. Other expense was $03.4 8 million for the three months ended ~~September~~December 3031, 2014, as compared to ~~other expense of~~ $10.38 million for the three months ended ~~September~~ 30December 31, 2013. The ~~decrease~~increase in other expense was primarily attributable to athe ~~decrease~~impairment inof debentures offset by lower interest expense and ana ~~increased cash~~gain ~~and~~on ~~non-cash~~the ~~gains~~change ~~from~~in ~~commodity~~fair ~~derivatives~~value ~~contracts~~of a derivative liability.

Six Months Ended December 31, 2014 Compared to Six Months Ended December 31, 2013

Revenues

Oil and Natural Gas Sales. During the six months ended December 31, 2014, we had oil and natural gas sales of $8.7 million, as compared to $10.2 million during the six months ended December 31, 2013. The decrease in oil and natural gas sales was primarily attributable to lower commodity prices.

Costs and Expenses

Exploration Expense. Exploration expense was $1.3 million for the six months ended December 31, 2014, as compared to $0.4 million for the six months ended December 31, 2013. The increase in exploration expense was attributable to seismic costs and dry hole expense.

Production Taxes. Production taxes were $0.7 million for the six months ended December 31, 2014, as compared to $1.2 million for the six months ended December 31, 2013. The decrease in production taxes was attributable to lower realized sales prices as a result of lower commodity prices.

Lease Operating Expenses. During the six months ended December 31, 2014, we incurred lease operating expenses of $2.2 million, as compared to $1.5 million during the six months ended December 31, 2013. The increase in lease operating expenses was attributable to costs related to a new Madera well and additional workover expenses.

Natural Gas Transportation and Marketing Expenses. For the six months ended December 31, 2014, natural gas transportation and marketing expenses was $137,000, as compared to $74,000 for the six months ended December 31, 2013.

Depreciation, Depletion, Amortization and Impairment. For the six months ended December 31, 2014, depreciation, depletion, amortization and impairment was $33.0 million, as compared to $4.3 million for the six months ended December 31, 2013. The increase in depreciation, depletion, amortization and impairment was attributable to impairment of our oil and gas assets resulting from significantly lower commodity prices.

General and Administrative Expense. General and administrative expense was $4.1 million for the six months ended December 31, 2014, as compared to $3.9 million for the six months ended December 31, 2013.

Other Expense. Other expense was $4.2 million for the six months ended December 31, 2014, as compared to other expense of $2.1 million for the six months ended December 31, 2013. The increase in other expense was primarily attributable to a loss on debentures of $3.8 million, partially offset by lower interest expense and a gain on the change in fair value of derivative liabilities.

Liquidity and Capital Resources

General

Our primary ~~sources~~source of liquidity for the ~~first~~ second quarter of fiscal 2015 ~~were~~was borrowings under our ~~Credit~~credit ~~Facility~~facility ~~and our cash flow from operations. Our ability to fund planned capital expenditures and to make acquisitions depends upon our future operating performance, availability of borrowings under~~ (the “Credit Facility,”) ~~and~~with ~~availability~~Independent ~~of equity and debt financing~~Bank, as ~~which~~lender is(the ~~affected~~“Lender”). Due byto ~~prevailing~~the ~~economic~~significant ~~conditions~~decline in ~~our~~oil ~~industry and~~prices ~~financial,~~since ~~business and other factors~~2014, ~~some~~we ofhave ~~which~~had ~~are~~limited ~~beyond our control. Our cash flow from operations is mainly influenced~~access byto ~~the~~capital ~~prices~~to weexecute ~~receive for~~ our ~~oil~~capital ~~and~~development ~~natural gas production and the quantity of oil and natural gas we produce~~plan. ~~Prices~~We ~~for oil and natural gas~~ are ~~affected~~currently byevaluating ~~national~~future ~~and~~options ~~international economic~~ and ~~political~~strategic ~~conditions, national and global supply and demand for hydrocarbons, seasonal weather influences and other factors beyond our control and have recently declined~~plans.

Capital Expenditures

Most of our capital expenditures are for the exploration, development, production and acquisition of oil and natural gas reserves. We anticipate cash capital expenditures of between $15 million and $20 million for the remainder of fiscal year 2015. We currently do not have access to sufficient funds for our planned exploration or development activities for the next twelve months and will need additional capital to continue our operations beyond March 31, 2015, or sooner if the Lender accelerates the repayment of our obligations under the Credit Facility. We are currently seeking funding for our 2015 capital development program.

Liquidity

At ~~September~~December 3031, 2014, we had $1.04 million in cash and cash equivalents, and $2627.8 million of total indebtedness under ~~the~~our Credit Facility and $45.90 million ofpursuant ~~our~~to the Company’s 10.0% Series A Cumulative Redeemable Preferred Stock, par value $0.0001 per share (the “Series A Preferred Stock”), net of a discount of $1.5 4 million. At ~~September~~December 3031, 2014, we had a working capital deficit of $3113.94 million compared to a working capital deficit of $16.12 million at ~~September~~December 3031, 2013. OfWe ~~the~~are ~~$31.9~~currently ~~million~~in ~~working~~default ~~capital~~under ~~deficit~~the atCredit ~~September 30~~Facility, ~~2014,~~and ~~$26.8 million relates~~the toLender ~~the~~has ~~reclassification of~~ the ~~full~~right ~~amount~~to ofaccelerate ~~the~~all amounts outstanding ~~borrowings~~ under the Credit Facility ~~from~~upon anotice ~~long-term liability~~ to athe ~~short-term liability on our Consolidated Balance Sheets as of September 30, 2014~~borrowers.

We are currently in default under the Credit Facility, and the Lender has the right to accelerate all amounts outstanding under the Credit Facility upon notice to the Borrowers. We are in discussions with the Lender regarding either a waiver of the non-compliance or an amendment to the Credit Agreement to cure the non-compliance. While we anticipate obtaining a waiver from the Lender, we cannot provide any assurance that these negotiations will be successful.

Cash Flows

Net cash ~~provided~~used byin operating activities was $10.91 million for the ~~three~~six months ended ~~September~~December 3031, 2014, compared to net cash ~~used~~provided inby operating activities of $05.40 million for the ~~three~~six months ended ~~September~~December 3031, 2013. The ~~increase~~decrease in net cash provided by operating activities was primarily due to ana ~~increase in net~~ loss of $137.60 million, ~~offset~~depreciation, ~~by an increase in~~ depletion, ~~depreciation,~~ amortization, and impairment of ~~approximately~~ $033.30 million, anand ~~increase~~loss inon ~~income~~debentures ~~from commodities derivatives~~ of ~~approximately~~ $03.78 million ~~and beneficial changes in working capital items~~.

Net cash used in investing activities ~~increased~~ decreased to $21.62 million for the ~~three~~six months ended ~~September~~December 3031, 2014 from $17.62 million for the ~~three~~six months ended ~~September 30~~December 31, 2013 due to fewer annew ~~increase~~oil inand ~~expenditures~~gas ~~for~~wells ~~drilling~~being ~~activity~~drilled.

Net cash provided by financing activities was $1.0 million for the ~~three~~six months ended ~~September~~December 3031, 2014, as compared to $53.27 million for the ~~three~~six months ended ~~September~~December 3031, 2013. Net cash provided by financing activities for the ~~three~~six months ended ~~September~~December 3031, ~~2013~~2014 was primarily comprised of ~~$10.7 million~~borrowings ofunder ~~net proceeds from~~ the ~~sale of shares of common stock and Series A Preferred Stock. These amounts were partially offset by $5.5 million of payments on the~~ Credit Facility ~~and convertible notes payable~~.

~~Indebtedness~~Credit Facility

~~Credit~~The ~~Facility.~~Senior ~~The~~First Lien Secured Credit Agreement ~~provides~~(as ~~for~~amended, the “Credit ~~Facility~~Agreement”) with Cross Border, ~~which~~Black ~~has~~Rock and RMR Operating (Red Mountain, Cross Border, Black Rock and RMR Operating, jointly and severally, the “Borrowers”) and the Lender, provides for a Credit Facility with a maturity date of February 5, 2016. The borrowing base under the Credit Facility is determined at the discretion of the Lender based on, among other things, the Lender’s estimated value of the proved reserves attributable to the Borrowers’ oil and natural gas properties that have been mortgaged to the Lender, and is subject to regular redeterminations on September 30 and March 31 of each year, and interim redeterminations described in the Credit Agreement and potentially monthly commitment reductions, in each case which may reduce the amount of the borrowing base. AsEffective ofApril ~~September~~21, 302015, ~~2014,~~ the borrowing base ~~was~~and commitment were reduced to $3012.04 million. The commitment is subject to a monthly commitment reduction of $125,000 beginning on July 1, 2015.

2021

Amounts outstanding under the Credit Facility ~~will~~ bear interest at a rate per annum equal to the greater of (x) the U.S. prime rate as published in The Wall Street Journal’s “Money Rates” table in effect from time to time and (y) 4.0%. Interest is payable monthly in arrears on the last day of each calendar month. Borrowings under the Credit Facility are secured by first priority liens on substantially all the property of each of the Borrowers and are unconditionally guaranteed by Doral West Corp. and Pure Energy Operating, Inc., each a subsidiary of Cross Border.

The Credit Agreement contains negative covenants that may limit the Borrowers’ ability to, among other things, incur liens, incur additional indebtedness, enter into mergers, sell assets, make investments and pay dividends. The Credit Agreement permits the payment of cash dividends on our Series A Preferred Stock so long as we are not otherwise in default under the Credit Agreement and payment of such cash dividends would not cause us to be in default under the Credit Agreement.

Amounts outstanding under the Credit Facility may be accelerated and become immediately due and payable upon specified events of default of Borrowers, including, among other things, a default in the payment of principal, interest or other amounts due under the Credit Facility, certain loan documents or hydrocarbon hedge agreements, failure to perform or observe covenants under the Credit ~~Facility~~Agreement, a material inaccuracy of a representation or warranty, a default of a covenant, a default with regard to certain loan documents which remains unremedied for a period of 30 days following notice, a default in the payment of other indebtedness of the Borrowers of $200,000 or more, bankruptcy or insolvency, certain changes in control, failure of the Lender’s security interest in any portion of the collateral with a value greater than $500,000, cessation of any security document to be in full force and effect, or Alan Barksdale ceasing to be Red Mountain’s Chief Executive Officer or Chairman of Cross Border and not being replaced with an officer acceptable to the Lender within 30 days.

21Pursuant to the Credit Agreement, at least one of the Borrowers is required to have acceptable hydrocarbon hedge agreements in place at all times effectively hedging at least 50% of the oil volumes of the Borrowers, derived from the most recent third party engineering report received by Lender covering a period of not less than eighteen (18) consecutive months.

Pursuant to the Credit Agreement, at least one of the Borrowers is required to have acceptable hedge agreements in place at all times effectively hedging at least 50% of the oil volumes of the Borrowers. Red Mountain has outstanding hedge agreements with various counterparties hedging a portion of the future oil production of the Borrowers. However, these hedge agreements did not comply with the volume and time period requirements of the Credit Agreement as of September 30, 2014.22

As of ~~September 30~~December 31, 2014, the Borrowers had collectively borrowed $2627.8 million and had no availability ~~of $3.2 million~~ under the Credit Facility. ~~On October 14, 2014, we borrowed an additional $1.0 million under the Credit Facility.~~ We were not in compliance with all of the financial covenants and the hedge agreement covenant under the Credit Facility described above at December ~~September 30~~31, 2014, which constitutes an event of default under the Credit Facility, and the Lender has the right to accelerate all amounts outstanding under the Credit Facility upon notice to the Borrowers. As a result, we have (i) recorded the full amount of the outstanding borrowings under the Credit Facility as a current liability on our Consolidated Balance Sheets as of ~~September 30~~December 31, 2014 and (ii) included a “going concern” note in our consolidated financial statements. As of November 1, 2015, the Borrowers had collectively borrowed $12.4 million and had no availability under the Credit Facility.

~~Series A Preferred Stock. As of September~~ ~~30, 2014, we had 254,463 shares of~~ Series A Preferred Stock outstanding. The Series A Preferred Stock is mandatorily redeemable and is not convertible into shares of our common stock. We classify the Series A Preferred Stock as a long-term liability, and we record dividends paid or accrued as interest expense in our condensed consolidated statements of operations.

InAs ~~August~~of ~~2013~~December 31, 2014, we ~~closed~~had ~~offerings of 376~~254,~~685~~463 ~~Units~~shares ~~(the “Units”). Each Unit consisted~~ of ~~one share of~~ Series A Preferred Stock ~~and one warrant to purchase up to 2~~outstanding.~~5 shares of common stock.~~ The ~~warrants~~Series ~~are~~A ~~exercisable~~Preferred ~~until~~Stock ~~the earlier of (i) August 2016 or (ii) the first trading day that~~ is atmandatorily ~~least~~redeemable 30 days after the date that we have provided notice to the holders of the warrants by filing a Current Report on Form 8-K stating that the common stock has (A) achieved a 20 trading day volume weighted average price of $15.00 per share or more and ~~(B)~~ ~~traded,~~is innot ~~the aggregate, 300,000 shares or more over the same 20 consecutive trading days for which the 20 trading day volume~~convertible ~~weighted~~into ~~average price was calculated; provided, that clause (ii) shall only be applicable so long as a warrant is exercisable for~~ shares of our common stock. We ~~The~~classify ~~warrants have an exercise price of $10.00 per share. The warrants issued with~~ the Series A Preferred Stock ~~were valued at $2.4 million. The value of the warrants is treated~~ as a ~~discount~~long-term toliability, ~~the Series A Preferred Stock~~ and ~~will be~~we ~~accreted~~record ~~over the life of the mandatorily redeemable preferred stock. Management determined the fair value using a probability~~dividends ~~weighted~~paid ~~Black-Scholes~~or ~~option~~accrued ~~model~~as ~~with~~interest aexpense ~~volatility~~in ~~based~~our oncondensed ~~the~~consolidated ~~historical~~statements ~~closing~~of ~~price~~operations. ofBecause ~~common~~we ~~stock~~are ofin ~~industry~~default ~~peers~~under ~~and~~ the Credit ~~closing~~Facility, ~~price~~as ofdescribed ~~our~~above, ~~common~~we ~~stock~~cannot onpay ~~the~~dividends ~~OTCBB~~ on the ~~date~~Series ofA ~~issuance.~~Preferred ~~The volatility and remaining term was approximately 55% and three years, respectively~~Stock.

In August 2013, we closed offerings of 476,687 Units (the “Units”). Each Unit consisted of one share of Series A Preferred Stock and one warrant to purchase up to 2.5 shares of common stock. The warrants are exercisable until the earlier of August 2016 or (ii) the first trading day that is at least 30 days after the date that we have provided notice to the holders of the warrants by filing a Current Report on Form 8-K stating that the common stock has (A) achieved a 20 trading day volume weighted average price of $15.00 per share or more and (B) traded, in the aggregate, 300,000 shares or more over the same 20 consecutive trading days for which the 20 trading day volume weighted average price was calculated; provided, that clause (ii) shall only be applicable so long as a warrant is exercisable for shares of common stock. The warrants have an exercise price of $10.00 per share. The warrants issued with the Series A Preferred Stock were valued at $2.4 million. The value of the warrants is treated as a discount to the Series A Preferred Stock and will be accreted over the life of the mandatorily redeemable preferred stock. Management determined the fair value using a probability weighted Black-Scholes option model with a volatility based on the historical closing price of common stock of industry peers and the closing price of our common stock on the OTCBB on the date of issuance. The volatility and remaining term was approximately 55% and three years, respectively.

The Series A Preferred Stock is mandatorily redeemable on July 15, 2018 at $25.00 per share, plus accrued and unpaid dividends to the redemption date, for a total redeemable value of $6.4 million.

For the three months ended September 30, 2014, we recognized total interest expense of $0.3 million related to the Series A Preferred Stock, which includes accretion of discount of $0.1 million.

Contractual Obligations

The following table presents our contractual obligations at September 30, 2014 (in thousands):

	Payments Due by Period
	Total		Less than 1 Year		1 – 3 Years		3 – 5 Years		More than 5 Years
Line of credit	$	26,800	$	26,800	$	—	$	—	$	—
Series A Preferred Stock		8,986		700		1,924		6,362		—
Environmental remediation liability		2,057		2,057		—		—		—
Asset retirement obligations		5,748		178		2,394		157		3,019
Lease obligations		373		192		181		—		—
Total	$	43,964	$	29,927	$	4,499	$	6,519	$	3,019

Off-Balance Sheet Arrangements

Since June 30, 2014, there have been no ~~material~~ material changes to our off-balance sheet arrangements ~~as reported in our Annual Report on Form 10-K for the fiscal year ended June 30, 2014~~.

Forward-Looking Statements

This Quarterly Report on Form 10-Q contains forward-looking statements within the meaning of Section 27A of the Securities Act of 1933, as amended, and Section 21E of the ~~Securities~~ Exchange Act ~~of 1934, as amended (the “Exchange Act”)~~. Statements that are not historical facts, including statements about our beliefs and expectations, are forward-looking statements. Forward-looking statements include statements preceded by, followed by or that include the words “may,” “could,” “would,” “should,” “believe,” “expect,” “anticipate,” “plan,” “estimate,” “target,” “project,” “intend,” “understand,” or similar expressions and the negative of such words and expressions, although not all forward-looking statements contain such words or expressions.

Forward-looking statements are only predictions and are not guarantees of performance. These statements generally relate to our plans, objectives and expectations for future operations and are based on management’s current beliefs and assumptions, which in turn are based on its experience and its perception of historical trends, current conditions and expected future developments as well as other factors it believes are appropriate under the circumstances. Although we believe that the plans, objectives and expectations reflected in or suggested by the forward-looking statements are reasonable, there can be no assurance that actual results will not differ materially from those expressed or implied in such forward-looking statements. Forward-looking statements also involve risks and uncertainties. Many of these risks and uncertainties are beyond our ability to control or predict and could cause results to differ materially from the results discussed in such forward-looking statements. Such risks and uncertainties include, but are not limited to, the following:

• our ability to generate sufficient cash flow from operations, borrowings or other sources to enable us to fully develop and produce our oil and natural gas properties;

• declines or volatility in the prices we receive for our oil and natural gas;

• general economic conditions, whether internationally, nationally or in the regional and local market areas in which we do business;

• risks associated with drilling, including completion risks, cost overruns and the drilling of non-economic wells or dry holes;

• uncertainties associated with estimates of proved oil and natural gas reserves;

• the presence or recoverability of estimated oil and natural gas reserves and the actual future production rates and associated costs;

• risks and liabilities associated with acquired companies and properties;

• risks related to integration of acquired companies and properties;

• potential defects in title to our properties;

• cost and availability of drilling rigs, equipment, supplies, personnel and oilfield services;

• geological concentration of our reserves;

• environmental or other governmental regulations, including legislation of hydraulic fracture stimulation;

• our ability to secure firm transportation for oil and natural gas we produce and to sell the oil and natural gas at market prices;

• exploration and development risks;

• management’s ability to execute our plans to meet our goals;

• our ability to retain key members of our management team;

• weather conditions;

• actions or inactions of third-party operators of our properties;

• costs and liabilities associated with environmental, health and safety laws;

•Forward-looking statements are only predictions and are not guarantees of performance. These statements generally relate to our plans, objectives and expectations for future operations and are based on management’s current beliefs and assumptions, which in turn are based on its experience and its perception of historical trends, current conditions and expected future developments as well as other factors it believes are appropriate under the circumstances. Although we believe that the plans, objectives and expectations reflected in or suggested by the forward-looking statements are reasonable, there can be no assurance that actual results will not differ materially from those expressed or implied in such forward-looking statements. Forward-looking statements also involve risks and uncertainties. Many of these risks and uncertainties are beyond our ability to ~~find~~control or predict and ~~retain~~could ~~highly~~cause ~~skilled~~results ~~personnel;~~to differ materially from the results discussed in such forward-looking statements. Such risks and uncertainties include, but are not limited to, the following:

•· ~~operating~~our ~~hazards~~ability ~~attendant~~ to ~~the~~raise ~~oil~~additional ~~and~~capital ~~natural~~to ~~gas~~fund ~~business~~future capital expenditures;

•· ~~competition~~our inability ~~the~~to generate sufficient cash flow from operations, borrowings or other sources to enable us to fully develop and produce our oil and natural gas ~~industry~~properties; ~~and~~

•· ~~the~~declines ~~other~~or ~~factors~~volatility ~~discussed under Item 1A. “Risk Factors”~~ in ~~our~~the ~~Annual~~prices ~~Report~~we onreceive ~~Form 10-K~~ for ~~the~~our ~~fiscal~~oil ~~year~~and ~~ended~~natural ~~June 30, 2014.~~gas;

general economic conditions, whether internationally, nationally or in the regional and local market areas in which we do business;

risks associated with drilling, including completion risks, cost overruns and the drilling of non-economic wells or dry holes;

uncertainties associated with estimates of proved oil and natural gas reserves;

the presence or recoverability of estimated oil and natural gas reserves and the actual future production rates and associated costs;

risks and liabilities associated with acquired companies and properties;

risks related to integration of acquired companies and properties;

potential defects in title to our properties;

cost and availability of drilling rigs, equipment, supplies, personnel and oilfield services;

geological concentration of our reserves;

environmental or other governmental regulations, including legislation of hydraulic fracture stimulation;

our ability to secure firm transportation for oil and natural gas we produce and to sell the oil and natural gas at market prices;

exploration and development risks;

management’s ability to execute our plans to meet our goals;

our ability to retain key members of our management team;

weather conditions;

actions or inactions of third-party operators of our properties;

costs and liabilities associated with environmental, health and safety laws;

our ability to find and retain highly skilled personnel;

operating hazards attendant to the oil and natural gas business;

competition in the oil and natural gas industry; and

the other factors discussed under Item 1A. “Risk Factors” in our Annual Report on Form 10-K for the fiscal year ended June 30, 2014 and our Quarterly Report on Form 10-Q for the fiscal quarter ended September 30, 2014.

Forward-looking statements speak only as of the date hereof. All such forward-looking statements and any subsequent written and oral forward-looking statements attributable to us or any person acting on our behalf are expressly qualified in their entirety by the cautionary statements contained or referred to in this section and any other cautionary statements that may accompany such forward-looking statements. Except as otherwise required by applicable law, we disclaim any duty to update any forward-looking statements.

Item 3.

Quantitative and Qualitative Disclosures About Market Risk

~~Commodity~~Not ~~Price~~applicable ~~Risk~~for a smaller reporting company.

Our major market risk exposure is the price we receive for our oil and natural gas production. Realized pricing is primarily driven by the prevailing price for oil and spot market prices for natural gas. Prices for oil and natural gas production are volatile and sometimes experience large fluctuations as a result of relatively small changes in supplies, weather conditions, economic conditions and government actions.

Pursuant to the Credit Agreement, at least one of the Borrowers is required to have acceptable hedge agreements in place at all times effectively hedging at least 50% of the oil volumes of the Borrowers. We have entered into derivative contracts, including costless collars, swaps, and puts, which hedge the price of oil for a portion of our expected production through January 2015.

The derivative contracts economically hedge against the variability in cash flows associated with the forecasted sale of our future oil production. While the use of the hedging arrangements will limit the downside risk of adverse price movements, it may also limit future gains from favorable movements.

The costless collars provide us with a lower limit “floor” price and an upper limit “ceiling” price on the hedged volumes. The floor price represents the lowest price we will receive for the hedged volumes while the ceiling price represents the highest price we will receive for the hedged volumes. The costless collars are settled monthly.

The swaps provide us with a fixed settlement price for our hedged volumes. The swaps are settled monthly.

The puts provide a fixed floor price on a notional amount of sales volumes while allowing full price appreciation if the relevant index price closes above the floor price.

We have elected not to designate our derivative financial instruments as hedges for accounting purposes, and accordingly, we record such contracts at fair value and recognize changes in such fair value in current earnings as they occur. Our commodity derivative contracts are carried at their fair value in earnings as they occur. We recognize unrealized and realized gains and losses related to these contracts on a mark-to-market basis in our condensed consolidated statements of operations under the caption “Gain (loss) on commodity derivatives”. Each derivative contract is evaluated separately to determine its own fair value. During the three months ended September 30, 2014, we recorded a gain on commodity derivative contracts of $0.3 million.

The following table summarizes our outstanding derivatives contracts with respect to future oil production as of September 30, 2014:

Commodity and Time Period	Contract Type	Volume Transacted	Contract Price
Crude Oil
October 1, 2014―November 30, 2014	Swap	2,000 Bbls/month	$93.50/Bbl
October 1, 2014―December 31, 2014	Put	1,979-8,330 Bbls/month	$95.00 - $100.00/Bbl
October 1, 2014―January 31, 2015	Put	6,000 Bbls/month	$95.00/Bbl

The fair values of our commodity derivatives are largely determined by estimates of the forward curves of the relevant price indices. As of September 30, 2014 and June 30, 2014, a 10% increase in underlying commodity prices would neither reduce nor increase the fair value of these derivatives by a material amount.

Interest Rate Risk

The Credit Facility exposes us to interest risk associated with interest rate fluctuations on outstanding borrowings. At each of September 30, 2014 and June 30, 2014, we had $26.8 million in outstanding borrowings under the Credit Facility. We incur interest on borrowings under the Credit Facility at a rate per annum equal to the greater of (x) the U.S. prime rate as published in The Wall Street Journal’s “Money Rates” table in effect from time to time and (y) 4.0% (which interest rate was 4.0% at September 30, 2014 and June 30, 2014). A hypothetical 10% change in the interest rates we pay on our borrowings under the Credit Facility as of each of September 30, 2014 and June 30, 2014 would result in an increase or decrease in our interest costs of approximately $107,000 per year.

Item 4.

Controls and Procedures

Evaluation of Disclosure Controls and Procedures

Disclosure controls and procedures are controls and other procedures that are designed to ensure that information required to be disclosed by us in reports that we file or submit under the Exchange Act is recorded, processed, summarized and reported, within the time periods specified in the Securities and Exchange Commission’s rules and forms. Disclosure controls and procedures include, without limitation, controls and procedures designed to ensure that information required to be disclosed in the reports that we file or submit under the Exchange Act is accumulated and communicated to our management, including our principal executive and principal financial officers, or persons performing similar functions, as appropriate to allow timely decisions regarding required disclosure. There are inherent limitations to the effectiveness of any system of disclosure controls and procedures. Accordingly, even effective disclosure controls and procedures can only provide reasonable assurance of achieving their control objectives.

Under the supervision and with the participation of our management, including our principal executive officer and principal financial officer, we evaluated the effectiveness of our disclosure controls and procedures as of ~~September~~December 3031, 2014 and, based on that evaluation, and as a result of the material weaknesses described in our Annual Report on Form 10-K for the fiscal year ended June 30, 2014, our principal executive officer and principal financial officer have concluded that our disclosure controls and procedures were not effective at the reasonable assurance level.

Changes in Internal Control Over Financial Reporting

~~There~~Due ~~have~~to ~~been~~a noreduction in staffing, there have been changes in our internal control over financial reporting that occurred during ~~our~~the ~~last~~ fiscal quarter ~~that~~ended December 31, 2014 that have materially affected, or are reasonably likely to materially affect, our internal control over financial reporting. Additionally, the Company anticipates a further reduction in staff that is reasonably likely to materially affect our internal control over financial reporting.

PART II. OTHER INFORMATION

Item 1. Legal Proceedings

~~There~~During the fiscal quarter ended December 31, 2014, there have been no material changes to the pending legal proceedings discussed in our Annual Report on Form 10-K for the fiscal year ended June 30, 2014., except as follows:

~~Item~~Cross 1ABorder was previously party to an engagement letter, dated February 7, 2012 (the “Engagement Letter”) with KeyBanc Capital Markets Inc. ~~Risk~~(“KeyBanc”) pursuant ~~Factors~~to which KeyBanc was to act as exclusive financial advisor to Cross Border’s board of directors in connection with a possible “Transaction” (as defined in the Engagement Letter). The Engagement Letter was formally terminated by Cross Border on August 21, 2012. The Engagement Letter provided that KeyBanc would be entitled to a fee upon consummation of a Transaction within a certain period of time following termination of the Engagement Letter. On May 16, 2013, KeyBanc delivered an invoice to Cross Border representing a fee and out-of-pocket expenses purportedly owed by Cross Border to KeyBanc as a result of the consummation of a purported Transaction that KeyBanc asserts had been consummated within the required time period. Cross Border disputed that any Transaction was consummated and that KeyBanc was entitled to any fees or out-of-pocket expenses. Cross Border filed a complaint seeking (i) a declaration that it was not liable to KeyBanc for any amounts in connection with the Engagement Letter, (ii) attorneys’ fees, and (iii) costs of suit. KeyBanc filed a counterclaim seeking (i) compensatory damages, (ii) interest, (iii) expenses and court costs, and (iv) reasonable and necessary attorneys’ fees. The matter was originally filed in the 44th Judicial District Court for the State of Texas, Dallas County but was subsequently removed to the United States District Court for the Northern District of Texas, Dallas Division. On August 26, 2014, Cross Border entered into a settlement agreement with KeyBanc, settling a lawsuit between the parties. In connection with the settlement, Cross Border agreed to pay KeyBanc $900,000 in three equal installments of $300,000 each on or before August 28, 2014, October 31, 2014 and December 31, 2014, and the parties agreed to mutual releases of liability related to the Engagement Letter. This balance was paid in full at December 31, 2014.

~~There~~In ~~have~~addition ~~been~~to nothe ~~material~~foregoing, ~~changes~~in to the ~~risk~~ordinary course of business, ~~factors~~the ~~discussed~~Company inis ~~our~~periodically ~~Annual~~a ~~Report~~party onto ~~Form~~various ~~10-K~~litigation ~~for~~matters ~~the~~that ~~fiscal~~it ~~year~~does ~~ended~~not ~~June~~believe ~~30,~~will ~~2014,~~have ~~except~~a asmaterial ~~follows:~~adverse effect on its results of operations or financial condition.

WeItem ~~were not in compliance with our covenants under our Credit Agreement as of September 30, 2014~~1A. AsRisk ~~a result, the Lender may exercise one or more of its remedies, including the right to accelerate the repayment of all outstanding borrowings.~~Factors

AsThere ofhave ~~September~~been ~~30,~~no ~~2014,~~material wechanges ~~had~~to ~~$26.8~~the ~~million~~risk offactors ~~borrowings~~discussed ~~under~~in our ~~Credit~~Annual ~~Facility.~~Report ~~This~~on ~~indebtedness~~Form is10-K ~~secured~~for ~~by substantially all of our assets and~~ the ~~assets~~ offiscal ~~our~~year ~~subsidiaries.~~ended ~~The~~June ~~Credit Agreement contains covenants which require us to maintain compliance with certain financial ratios, aging of accounts payable and agreements that hedge the price of oil. As of September~~ 30, 2014, ~~we were not in compliance with certain of these covenants~~ and, asour aQuarterly ~~result,~~Report the Lender can declare an event of default under the Credit Agreement. In the event of an event of default, the Lender has the right to accelerate repayment of all outstanding indebtedness and take actions to collect monies owed to it, including enforcing and foreclosing on ~~its security~~Form ~~interest~~10-Q onfor ~~our assets and~~ the ~~assets~~fiscal ofquarter ~~our~~ended ~~subsidiaries.~~September ~~In addition~~30, ~~the Lender can restrict our access to additional borrowings under the Credit Facility. As of the date hereof~~2014, ~~the~~except ~~Lender~~as ~~has not accelerated our repayment obligations or taken any of the other actions described above.~~follows:

WeDepressed ~~are~~oil inand ~~discussions~~gas ~~with~~natural ~~the~~prices ~~Lender~~have ~~regarding~~significantly ~~either~~adversely aaffected ~~waiver~~our results of ~~the~~operations, ~~non-compliance~~financial orcondition anand ~~amendment~~ability to ~~the~~meet Credit Agreement to cure the non-compliance. However, we cannot provide any assurance that these negotiations will be successful. Even if we successfully obtain a waiver or an amendment that cures the non-compliance, we can provide no assurance that we will not violate our ~~covenants~~capital inexpenditure ~~the future~~obligations.

IfOur ~~the~~revenue, ~~Lender~~profitability, ~~were~~access to ~~accelerate our repayment~~capital ~~obligation~~and ~~under~~future ~~the~~rate ~~Credit~~of ~~Facility,~~growth ~~our~~are ~~assets~~substantially ~~may~~dependent ~~not~~on bethe ~~sufficient~~prevailing toprices ~~fully~~of, ~~repay~~and ~~the~~demand ~~debt~~for, oil and wenatural ~~may~~gas. ~~not~~Oil beprices have ~~able~~declined tosubstantially ~~obtain capital~~since ~~from~~mid-2014 ~~other~~and ~~sources~~have atexperienced ~~favorable~~significant ~~terms~~volatility orduring ~~at all~~2015. IfThe ~~additional~~market ~~funding~~price isof ~~required,~~Brent ~~this~~crude oil ~~funding~~has ~~may~~decreased ~~not~~approximately be50% ~~available~~since ~~on favorable~~June ~~terms,~~2014 ifas ata ~~all,~~result orof ~~without~~market ~~potentially~~uncertainties ~~very~~over ~~substantial~~the ~~dilution~~supply and demand of oil due to increased ~~our~~production ~~stockholders.~~in Ifcertain weregions, dodecisions ~~not~~made ~~raise~~by OPEC, the ~~necessary funds,~~current westate ~~may~~of ~~need~~the toglobal ~~curtail~~economy orand ~~cease~~concerns ~~our~~over ~~operations,~~future global ~~sell~~oil ~~certain~~demand. ~~assets~~Historically, oil and~~/or~~ ~~file~~natural ~~for~~gas ~~bankruptcy,~~prices ~~which~~and ~~would~~markets have abeen ~~material adverse~~volatile, ~~effect~~and onthey ~~our~~are ~~financial~~likely ~~condition~~to ~~and~~continue ~~results~~to be ofvolatile ~~operations~~in the future.

~~While~~Continued ~~the~~depressed ~~Lender~~oil ~~has~~prices or a further decrease in oil or natural gas prices will not ~~accelerated~~only ~~the~~reduce ~~repayment of~~revenues, ~~our~~but ~~obligations~~will ~~under~~also reduce the ~~Credit~~quantities ~~Facility~~of reserves that are commercially recoverable, ~~its~~make ~~ability~~some towells douneconomical soto ~~has~~drill ~~caused~~or ~~all~~operate, ofreduce our ~~outstanding~~ability ~~indebtedness~~to ~~under~~develop ~~the~~our ~~Credit Facility~~properties, reduce our access to becapital ~~classified~~and asmay aresult ~~current~~in ~~liability~~charges onto ~~our~~earnings ~~consolidated~~for ~~balance~~impairment ~~sheets~~of atthe ~~September~~value ~~30,~~of ~~2014~~these assets.

We currently do not have sufficient funds to continue our exploration and development activities beyond March 31, 2015, or sooner if the Lender accelerates the repayment of our obligations under the Credit Facility.26

~~The~~Oil ~~oil~~ and natural gas ~~industry~~are iscommodities ~~capital~~and, ~~intensive.~~therefore, Wetheir ~~make~~prices ~~and~~are ~~expect~~subject to ~~continue~~wide tofluctuations ~~make~~in ~~significant~~response ~~capital~~to ~~expenditures~~relatively inminor ~~our~~changes ~~business~~in ~~for~~supply ~~the~~and ~~exploration~~demand, ~~development, production~~ and ~~acquisition~~numerous factors ofbeyond ~~oil~~our ~~and natural gas reserves~~control. ~~Improvement~~These infactors ~~commodity~~include ~~prices~~the ~~may result in an increase in our actual capital expenditures.~~following:

We· ~~plan~~worldwide toand ~~spend~~regional ~~between~~economic ~~$15~~conditions ~~million~~impacting the global supply and ~~$20 million~~demand ~~during~~for oil and natural gas; · the ~~remainder~~price and quantity of ~~fiscal~~imports ~~2015~~of foreign oil and natural gas; · the actions of OPEC and other state-controlled oil companies relating to ~~drill~~oil and ~~complete~~natural ~~wells~~gas price and production control; · political conditions in or reaffecting other oil-~~enter~~producing and ~~complete~~natural ~~wells.~~gas-producing ~~However~~countries, asincluding ofthe ~~September 30,~~current ~~2014,~~conflicts wein ~~had~~the aMiddle ~~working~~East ~~capital~~and ~~deficit~~conditions in South America and Russia; · the level of ~~$31.9~~global ~~million.~~oil Weand ~~currently~~natural dogas ~~not~~inventories; ~~have~~· ~~sufficient~~localized ~~funds~~supply toand ~~continue~~demand ~~our~~fundamentals; ~~exploration~~ · the availability of refining capacity; · price and ~~development~~availability ~~activities~~of ~~beyond~~transportation ~~March~~and ~~31,~~pipeline ~~2015,~~systems orwith ~~sooner~~adequate ifcapacity; ~~the~~· ~~Lender~~weather ~~accelerates~~conditions ~~our~~and ~~obligations~~natural ~~under~~disasters; ~~the~~· ~~Credit~~governmental ~~Agreement. If~~regulations; we· ~~are~~speculation ~~unable~~as to ~~finance~~the ~~our~~future ~~operations~~price onof ~~acceptable~~oil ~~terms~~and ornatural atgas ~~all,~~and wethe ~~may~~speculative betrading ~~forced~~of tooil ~~curtail~~and ornatural ~~suspend~~gas ~~our~~futures ~~planned~~contracts; ~~exploration~~ · price and ~~development~~availability ~~activities~~of competitors’ supplies of oil and ~~our~~natural ~~business,~~gas; ~~financial~~· ~~condition~~energy conservation and ~~results~~environmental measures; · technological advances affecting energy consumption; · the price and availability of ~~operations~~alternative ~~may~~fuels beand ~~materially~~energy sources; and ~~adversely~~· ~~affected~~domestic and international drilling activity.

26It is impossible to predict future oil and natural gas price movements, and current depressed prices or further declines in oil and natural gas prices could have a material adverse effect on our liquidity and financial condition.

~~Our~~We ~~cash~~intend ~~flows~~to ~~from~~deregister ~~operations~~our ~~and~~securities ~~access~~under tothe Exchange ~~capital~~Act. ~~are~~Deregistration ~~subject~~will toresult ain ~~number~~less disclosure about us and may negatively affect the liquidity and trading prices of ~~variables,~~our common ~~including:~~stock.

•On ~~the~~November ~~value~~13, 2015, our Board of Directors voted to the voluntarily deregister our ~~proved~~common ~~reserves;~~stock, •our 10.0% Series A Cumulative Redeemable Preferred Stock (the ~~level~~“Series A Preferred Stock”) and warrants under the Exchange Act and become a non-reporting company. In connection therewith, the Board of ~~oil~~Directors approved the filing with the SEC of a Form 15 to voluntarily deregister our securities under Section 12(g) of the Exchange Act and ~~natural~~suspend ~~gas~~our wereporting ~~are~~obligations ~~able~~under Section 15(d) of the Exchange Act. We expect to ~~produce~~file ~~from~~the ~~existing~~Form ~~wells;~~15 •on or about November 13, 2015. We expect that our obligations to file periodic reports, such as Annual Reports on Form 10-K, Quarterly Reports on Form 10-Q and Current Reports on Form 8-K, will be suspended immediately upon the ~~prices~~filing atof ~~which~~the Form 15 with the SEC, and our ~~oil~~proxy statement, Section 16 and ~~natural~~other ~~gas~~Section 12(g) reporting responsibilities will terminate effective 90 days after the filing of the Form 15. We are ~~sold;~~eligible •to deregister under the Exchange Act because our ~~ability~~common stock, Series A Preferred Stock and warrants are each held by fewer than 300 shareholders of record. Following deregistration, we do not expect to ~~acquire~~publish periodic financial information or furnish such information to its stockholders except as may be required by applicable laws. As a result of the foregoing factors, ~~locate~~deregistration ~~and~~will ~~produce~~result in ~~new~~less ~~reserves;~~disclosure about us and •may negatively affect the ~~ability~~liquidity and trading prices of our ~~banks~~common ~~to lend~~stock.

~~Debt financing could lead to:~~27

•Item a2. ~~substantial~~Unregistered ~~portion~~Sales of ~~operating~~Equity ~~cash~~Securities ~~flow~~and ~~being~~Use ~~dedicated to the payment~~ of ~~principal and interest; • us being more vulnerable to competitive pressures and economic downturns; and • restrictions on our operations, including our ability to pay dividends.~~Proceeds

If sufficient capital resources are not available, we might be forced to cease operations entirely, curtail developmental and exploratory drilling and other activities or be forced to sell some assets on an untimely or unfavorable basis, which would have a material adverse effect on our business, financial condition and results of operationsNone.

Item 23. ~~Unregistered~~Defaults ~~Sales~~Upon ofSenior ~~Equity~~ Securities ~~and Use of Proceeds~~

None.

Item 34. ~~Defaults~~Mine ~~Upon~~Safety ~~Senior Securities~~Disclosures

~~None~~Not applicable.

Item 45. ~~Mine~~Other ~~Safety Disclosures~~Information

~~Not applicable~~None.

Item 56. ~~Other Information~~Exhibits

None.

3.1		Certificate of Formation of Red Mountain Resources, Inc. (incorporated by reference to Exhibit 3.2 to the Company’s Current Report on Form 8-K filed on February 4, 2014).

3.2		Bylaws of Red Mountain Resources, Inc. (incorporated by reference to Exhibit 3.3 to the Company’s Current Report on Form 8-K filed on February 4, 2014).

4.1		Form of Common Stock Certificate of Red Mountain Resources, Inc. (incorporated by reference to Exhibit 4.1 to the Company’s Current Report on Form 8-K filed on February 4, 2014).

4.2		Form of 10.0% Series A Cumulative Redeemable Preferred Stock Certificate of Red Mountain Resources, Inc. (incorporated by reference to Exhibit 4.2 to the Company’s Current Report on Form 8-K filed on February 4, 2014).

4.3		Form of Warrant Certificate of Red Mountain Resources, Inc. (incorporated by reference to Exhibit 4.3 to the Company’s Current Report on Form 8-K filed on February 4, 2014).

4.4		Form of Warrant Agreement between the Company and Broadridge Corporate Issuer Solutions, Inc. (incorporated by reference to Exhibit 4.4 to the Company’s Registration Statement on Form 8-A filed on July 24, 2013).

4.5		Amendment No. 1 to Warrant Agreement, effective as of January 31, 2014, between Broadridge Corporate Issuer Solutions, Inc. and Red Mountain Resources, Inc. (incorporated by reference to Exhibit 10.1 to the Company’s Current Report on Form 8-K filed on February 4, 2014).

31.1*		Certification of the Chief Executive Officer of the Company, pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.

31.2*		Certification of the Chief Financial Officer of the Company, pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.

32.1**		Certification of the Chief Executive Officer and Chief Financial Officer of the Company, pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.

2728

Item 6. Exhibits

101.INS*		XBRL Instance Document

101.SCH*		XBRL Taxonomy Extension Schema Document

3.1	Certificate of Formation of Red Mountain Resources, Inc. (incorporated by reference to Exhibit 3.2 to the Company’s Current Report on Form 8-K filed on February 4, 2014).
101.CAL*		XBRL Taxonomy Extension Calculation Linkbase Document
3.2	Certificate of Correction to the Certificate of Formation of Red Mountain Resources, Inc. (incorporated by reference to Exhibit 3.1 to the Company’s Current Report on Form 8-K filed on August 11, 2014).
101.DEF*		XBRL Taxonomy Extension Definition Linkbase Document
3.3	Bylaws of Red Mountain Resources, Inc. (incorporated by reference to Exhibit 3.3 to the Company’s Current Report on Form 8-K filed on February 4, 2014).
101.LAB*		XBRL Taxonomy Extension Label Linkbase Document
4.1	Form of Common Stock Certificate of Red Mountain Resources, Inc. (incorporated by reference to Exhibit 4.1 to the Company’s Current Report on Form 8-K filed on February 4, 2014).
101.PRE*		XBRL Taxonomy Extension Presentation Linkbase Document
4.2	Form of 10.0% Series A Cumulative Redeemable Preferred Stock Certificate of Red Mountain Resources, Inc. (incorporated by reference to Exhibit 4.2 to the Company’s Current Report on Form 8-K filed on February 4, 2014).
4.3	Form of Warrant Certificate of Red Mountain Resources, Inc. (incorporated by reference to Exhibit 4.3 to the Company’s Current Report on Form 8-K filed on February 4, 2014).
4.4	Form of Warrant Agreement between the Company and Broadridge Corporate Issuer Solutions, Inc. (incorporated by reference to Exhibit 4.4 to the Company’s Registration Statement on Form 8-A filed on July 24, 2013).
4.5	Amendment No. 1 to Warrant Agreement, effective as of January 31, 2014, between Broadridge Corporate Issuer Solutions, Inc. and Red Mountain Resources, Inc. (incorporated by reference to Exhibit 10.1 to the Company’s Current Report on Form 8-K filed on February 4, 2014).
31.1*	Certification of the Chief Executive Officer of the Company, pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
31.2*	Certification of the Chief Financial Officer of the Company, pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
32.1**	Certification of the Chief Executive Officer and Chief Financial Officer of the Company, 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

* Filed herewith. ** Furnished herewith.

28** Furnished herewith.

~~Signatures~~29

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

	RED MOUNTAIN RESOURCES, INC.
	By:	/s/ Alan W. Barksdale
		Alan W. Barksdale
		Chief Executive Officer
	By:	/s/ Hilda D. Kouvelis
		Hilda D. Kouvelis
		Chief Accounting Officer
	Date: November 17, 2014

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

29Red Mountain Resources, Inc. By: /s/ Alan W. Barksdale Alan W. Barksdale Chief Executive Officer

INDEX TO EXHIBITS


	By:	/s/ Hilda D. Kouvelis
		Hilda D. Kouvelis
		Chief Accounting Officer

	Date: November 13, 2015

3.1	Certificate of Formation of Red Mountain Resources, Inc. (incorporated by reference to Exhibit 3.2 to the Company’s Current Report on Form 8-K filed on February 4, 2014).
3.2	Certificate of Correction to the Certificate of Formation of Red Mountain Resources, Inc. (incorporated by reference to Exhibit 3.1 to the Company’s Current Report on Form 8-K filed on August 11, 2014).
3.3	Bylaws of Red Mountain Resources, Inc. (incorporated by reference to Exhibit 3.3 to the Company’s Current Report on Form 8-K filed on February 4, 2014).
4.1	Form of Common Stock Certificate of Red Mountain Resources, Inc. (incorporated by reference to Exhibit 4.1 to the Company’s Current Report on Form 8-K filed on February 4, 2014).
4.2	Form of 10.0% Series A Cumulative Redeemable Preferred Stock Certificate of Red Mountain Resources, Inc. (incorporated by reference to Exhibit 4.2 to the Company’s Current Report on Form 8-K filed on February 4, 2014).
4.3	Form of Warrant Certificate of Red Mountain Resources, Inc. (incorporated by reference to Exhibit 4.3 to the Company’s Current Report on Form 8-K filed on February 4, 2014).
4.4	Form of Warrant Agreement between the Company and Broadridge Corporate Issuer Solutions, Inc. (incorporated by reference to Exhibit 4.4 to the Company’s Registration Statement on Form 8-A filed on July 24, 2013).
4.5	Amendment No. 1 to Warrant Agreement, effective as of January 31, 2014, between Broadridge Corporate Issuer Solutions, Inc. and Red Mountain Resources, Inc. (incorporated by reference to Exhibit 10.1 to the Company’s Current Report on Form 8-K filed on February 4, 2014).
31.1*	Certification of the Chief Executive Officer of the Company, pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
31.2*	Certification of the Chief Financial Officer of the Company, pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
32.1**	Certification of the Chief Executive Officer and Chief Financial Officer of the Company, 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

INDEX TO EXHIBITS

* Filed herewith. ** Furnished herewith.

3.1		Certificate of Formation of Red Mountain Resources, Inc. (incorporated by reference to Exhibit 3.2 to the Company’s Current Report on Form 8-K filed on February 4, 2014).

3.2		Bylaws of Red Mountain Resources, Inc. (incorporated by reference to Exhibit 3.3 to the Company’s Current Report on Form 8-K filed on February 4, 2014).

4.1		Form of Common Stock Certificate of Red Mountain Resources, Inc. (incorporated by reference to Exhibit 4.1 to the Company’s Current Report on Form 8-K filed on February 4, 2014).

4.2		Form of 10.0% Series A Cumulative Redeemable Preferred Stock Certificate of Red Mountain Resources, Inc. (incorporated by reference to Exhibit 4.2 to the Company’s Current Report on Form 8-K filed on February 4, 2014).

4.3		Form of Warrant Certificate of Red Mountain Resources, Inc. (incorporated by reference to Exhibit 4.3 to the Company’s Current Report on Form 8-K filed on February 4, 2014).

4.4		Form of Warrant Agreement between the Company and Broadridge Corporate Issuer Solutions, Inc. (incorporated by reference to Exhibit 4.4 to the Company’s Registration Statement on Form 8-A filed on July 24, 2013).

4.5		Amendment No. 1 to Warrant Agreement, effective as of January 31, 2014, between Broadridge Corporate Issuer Solutions, Inc. and Red Mountain Resources, Inc. (incorporated by reference to Exhibit 10.1 to the Company’s Current Report on Form 8-K filed on February 4, 2014).

31.1*		Certification of the Chief Executive Officer of the Company, pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.

31.2*		Certification of the Chief Financial Officer of the Company, pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.

32.1**		Certification of the Chief Executive Officer and Chief Financial Officer of the Company, 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

30* Filed herewith.

**	Furnished herewith.

Filing Compare · RED MOUNTAIN RESOURCES, INC.