UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q

(Mark One)

[x]

QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE

SECURITIES EXCHANGE ACT OF 1934

For the quarterly period ended ~~June~~September 30, 2012

[ ]

TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE

SECURITIES EXCHANGE ACT OF 1934


For the transition period from		to

Commission file number 333-125068

[hpgs10q3q2012001.jpg]

High Plains Gas, Inc.

(Exact name of registrant as specified in its charter)

Nevada	26-3633813
(State or other jurisdiction of incorporation or organization)	(I. R. S. Employer Identification No.)
1200 East Lincoln, Gillette, WY	~~82716~~82717
(Address of principal executive offices)	(Zip Code)

	(307) 686-5030
	(307) 752-5731
	(Registrant’s telephone number, including area code)
	Copies of all communications should be sent to: Cutler Law Group 3355 W Alabama, Ste 1150 Houston, Texas 77098 Tel: (713) 888-0040 / Fax: (800) 836-0714 Email: rcutler@cutlerlaw.com
	Copies of all communications should be sent to: Cutler Law Group 2800 Post Oak Blvd., Suite 4100, Houston, Texas 77056 Tel: (713) 888-0040 / Fax: (800) 836-0714 Email: rcutler@cutlerlaw.com
	3601 Southern Drive, Gillette, WY 82718
	(Former name, former address and former fiscal year, if changed since last report)
Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days.		Yes [x ] No [x]
Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files).		Yes [x] No [ ]

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

Large accelerated filer [ ]

Accelerated filer [ ]

Non-accelerated filer [ ]

(Do not check if a smaller reporting company)

Smaller reporting company [x]



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

The number of shares of the registrant’s common stock outstanding as of ~~August~~March 28, ~~2012~~2014 was ~~348~~299,~~812~~239,~~512~~076 shares.

HIGH PLAINS GAS, INC.

TABLE OF CONTENTS

		Page
PART I - FINANCIAL INFORMATION
Item 1.	Financial Statements	4
Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	2932
Item 3.	Quantitative and Qualitative Disclosures About Market Risk	3540
Item 4.	Controls and Procedures	3540
PART II – OTHER INFORMATION
Item 1.	Legal Proceedings	3741
Item 1A	Risk Factors	3742
Item 2.	Unregistered Sales of Equity Securities and Use of Proceeds	3742
Item 3.	Default upon Senior Securities	3843
Item 4.	Mine Safety Disclosures	3843
Item 5.	Other Information	3843
Item 6.	Exhibits	3944
SIGNATURES		43

HIGH PLAINS GAS, INC.

CONDENSED CONSOLIDATED BALANCE SHEETS

~~JUNE~~SEPTEMBER 30, 2012 AND DECEMBER 31, 2011

	June 30, 2012	December 31, 2011
	September 30, 2012	December 31, 2011
	(Unaudited)
ASSETS
Current Assets:
Cash and cash equivalents	$ ~~383~~44,~~766~~681	$ ~~435~~321,~~015~~227
Accounts receivable, net	~~1,804,305~~-	41,~~055~~080,~~189~~967
Deferred financing fees, net	~~103~~48,~~844~~106	89,905
Rebates receivable, accounts receivable sales	276,661	-
Bond commitment fees, net	86,849	100,140
Bond commitment fees, net	140,959	100,140
Funds in escrow	-	750,000
Commodity hedge	~~1,094,602~~-	2,182,400
Prepaid and other	~~239~~52,~~384~~572	9977,~~766~~199
Total current assets	4,043,521	7,712,415
Assets of discontinued operations	-	9,914,556
Total current assets	232,208	14,516,394
Natural Gas Properties-using successful efforts method	44,114,691	43,553,233
Less accumulated depletion, depreciation, amortization and impairment	(44,114,691)	(29,810,300)
Natural gas properties-net	-	13,742,933
Property, Plant and Equipment-net	~~2,291,620~~-	2326,~~293,292~~776
Certificates of deposit – restricted	~~201,988~~-	201,988
Other Assets-net	~~3,724,730~~-	7147,~~647,166~~196
Total Assets	$ 10232,~~261,859~~208	$ 3128,~~597~~935,~~794~~287
LIABILITIES AND STOCKHOLDERS’ (DEFICIT)
LIABILITIES AND STOCKHOLDERS’ DEFICIT
Current Liabilities:
Accounts payable and accrued liabilities	$ 1915,~~819~~891,~~400~~320	$ 1614,~~314~~380,~~313~~470
Current portion-term debt	961,848	1,889,809
Current portion - term debt	667,415	-
Current portion - lines of credit	65,~~102~~315,~~786~~694	6,~~240~~225,~~563~~439
Notes payable – related parties	13,~~593~~393,~~950~~949	3,~~423~~398,~~837~~838
Total current liabilities	28,477,984	27,868,522
Liabilities of discontinued operations	4,673,158	-
Notes Payable – related parties	1,900,000	3,000,000
Total current liabilities	29,941,536	24,004,747
Debt Obligations – term debt, net of current	~~371,898~~-	~~414~~4,~~651~~615,919
Asset Retirement Obligation	9,679,815	9,320,074
Total liabilities	4039,~~429~~621,~~697~~351	4037,~~603~~940,~~247~~740
Stockholders’ Deficit:
Preferred stock - $.001 par value: 20,000,000 authorized; 0 issued and outstanding	-	-
Series A Convertible Preferred stock - $1,000 par value: 2,500 authorized; 810.971 and 0 issued and outstanding, respectively	810,971	810,971
Series A Convertible Preferred stock - $1,000 par value: 2,500 authorized; 810.971 and 810.971 issued and outstanding, respectively	810,971	810,971
Common stock - $.001 par value: 500,000,000 authorized; 348,812,512 and 275,714,410 issued and outstanding, respectively	348,812	275,714
Common stock - $.001 par value: 500,000,000 authorized; 353,239,076 and 275,714,410 issued and outstanding, respectively	353,239	275,714
Additional paid in capital	61,~~151~~773,~~460~~658	53,229,680
Accumulated (deficit)	(92,479,081)	(63,321,818)
Accumulated deficit	(102,327,011)	(63,321,818)
Total stockholders’ (deficit)	(30,167,838)	(9,005,453)
Total stockholders’ deficit	(39,389,143)	(9,005,453)
Total Liabilities and Stockholders’ (Deficit)	$ 10,261,859	$ 31,597,794
Total Liabilities and Stockholders’ Deficit	$ 232,208	$ 28,935,287

See accompanying notes to these unaudited condensed consolidated financial statements

HIGH PLAINS GAS, INC.

CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS

FOR THE THREE MONTHS ENDED ~~JUNE~~SEPTEMBER 30, 2012 AND 2011

(UNAUDITED)

	For The Three Months Ended June 30,
		For The Three Months Ended September 30,
	~~2012~~	2012	~~2011~~	2011
Revenues
Natural gas revenue	~~$ 619,542~~	$ -	~~$ 3,379,997~~	$ 2,784,663
Service revenue	~~5,628,374~~	-	-	-
Total Revenue	~~6,247,916~~	-	~~3,379,997~~	2,784,663
Costs and Expenses
Lease operating expense and production taxes	~~2,496,361~~	228,999	~~3,166,764~~	1,514,961
Cost of services	5,389,391		-
General and administrative expense		1,462,578		1,759,713
General and administrative expense	2,444,931		4,021,289
Depreciation, depletion, amortization and accretion		247,504		1,844,446
Depreciation, depletion and amortization	1,021,173		1,364,096
Other operating expenses		-		10,872
Other operating expenses	581,292		234,347
Amortization of bond commitment / financing fees		109,848		807,743
Amortization of bond commitment / financing fees	35,832		742,262
Realized commodity hedge (gain)		(52,837)		(129,140)
Realized commodity hedge (gain)	(1,072,170)		(56,760)
Impairment of natural gas properties		-		2,565,270
Impairment of natural gas properties	12,953,082		4,125,010
Impairment expense – other assets		240,757		-
Impairment expense - intangibles	3,604,645		-
Abandonment of natural gas properties		-		2,748
Accretion of asset retirement obligation	172,468		219,224
Total Costs and Expenses		2,236,849		8,376,613
Total Costs and Expenses	27,627,005		13,816,232
Operating (loss) from continuing operations		(2,236,849)		(5,591,950)
Operating (Loss)	(21,379,089)		(10,436,235)
Other Income (Expense)
Other Income (Expense)
Other income expense		61,048		27,522
Other income (expense)	13,653		54,275
(Loss) on valuation of equity securities		-		(1,751,602)
(Loss) on valuation of equity securities	-		(890,257)
Unrealized commodity hedge gain (loss)		-		1,157,117
Unrealized commodity hedge gain (loss)	(1,460,312)		392,699
(Loss) on extinguishment of debt and liabilities		(360,015)		(4,323,581)
(Loss) on extinguishment of debt	(37,181)		(532,932)
Interest (expense)		(1,941,601)		(549,843)
Interest (expense)	(450,418)		(392,251)
Total Other Income (Expense)		(2,240,568)		(5,440,387)
Total Other Income (Expense)	(1,934,258)		(1,368,466)
Net (loss) from continuing operations		$ (4,477,417)		$ (11,032,337)
Net (Loss)	$ (23,313,347)		$ (11,804,701)
Loss from discontinued operations		(5,353,241)		-
Preferred stock dividend	(36,405)		-
Net (loss)		$ (9,830,658)		$ (11,032,337)
Net (Loss) applicable to common stockholders	(23,276,942)		$ (11,804,701)
	Preferred stock dividend	(30,405)		-
Net (Loss) per share	$ (0.07)		$ (0.07)
	Net (loss) applicable to common stockholders	(9,861,063)		$ (11,032,337)
Weighted average number of common shares outstanding – basic and diluted	347,646,363		167,314,447
	Basic and diluted net (loss) per share:
	Continuing operations	$ (0.01)		$ (0.06)
	Discontinued operations	(0.02)		-
	Total basic and diluted net (loss) per share	$ (0.03)		$ (0.06)
	Weighted average number of common shares outstanding – basic and diluted	351,324,443		181,547,173

See accompanying notes to these unaudited condensed consolidated financial statements

HIGH PLAINS GAS, INC.

CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS

FOR THE ~~SIX~~NINE ~~MONTH~~MONTHS ~~SENDED~~ENDED ~~JUNE~~SEPTEMBER 30, 2012 AND 2011

(UNAUDITED)

	For The Six Months Ended June 30,
		For The Nine Months Ended September 30,
	~~2012~~	2012	~~2011~~	2011
Revenues
Natural gas revenue	~~$ 2,143,458~~	$ 2,143,458	~~$ 7,407,081~~	$ 10,191,744
Service revenue	~~12,038,509~~	-	-	-
Total Revenue	~~14,181,967~~	2,143,458	~~7,407,081~~	10,191,744
Costs and Expenses
Lease operating expense and production taxes	~~4,561,739~~	4,790,737	~~7,292,902~~	10,443,214
Cost of services	11,536,832		-
General and administrative expense		6,693,859		6,401,347
General and administrative expense	5,603,875		6,276,985
Depreciation, depletion, amortization and accretion		2,461,445		5,580,557
Depreciation, depletion and amortization	1,971,347		3,347,365
Other operating expenses		581,292		684,389
Other operating expenses	581,292		673,517
Amortization of bond commitment / financing fees		341,801		2,403,173
Amortization of bond commitment / financing fees	231,954		1,595,430
Realized commodity hedge (gain)		(771,733)		(337,645)
Realized commodity hedge (gain)	(1,806,696)		(208,505)
Impairment of gas properties		13,440,869		2,565,270
Impairment of gas properties	13,440,869		4,125,010
Impairment expense – other assets		240,757		-
Impairment expense - intangibles	3,604,645		-
Abandonment of oil and gas properties		-		4,127,758
Accretion of asset retirement obligation	359,741		388,746
Total Costs and Expenses		27,779,027		31,868,063
Total Costs and Expenses	40,085,598		23,491,450
Operating (loss) from continuing operations		(25,635,569)		(21,676,319)
Operating (Loss)	(25,903,631)		(16,084,369)
Other Income (Expense)
Other Income (Expense)
Other income (expense)		(183,469)		88,665
Other income (expense)	(244,516)		61,143
(Loss) on valuation of equity securities		-		(2,645,108)
(Loss) on valuation of equity securities	--		(893,506)
Unrealized commodity hedge gain (loss)		-		1,128,902
Unrealized commodity hedge (loss)	(1,087,799)		(28,215)
Loss on extinguishment of debt and other liabilities		(1,649,314)		(4,856,513)
Loss on extinguishment of debt	(1,289,299)		(532,932)
Interest (expense)		(2,516,143)		(1,855,288)
Interest (expense)	(648,290)		(1,305,445)
Total Other Income (Expense)		(4,348,926)		(8,139,342)
Total Other Income (Expense)	(3,269,904)		(2,698,955)
Net (loss) from continuing operations		$ (29,984,495)		$ (29,815,661)
Net (Loss)	$ (29,173,535)		$ (18,783,324)
Loss from discontinued operations		(9,019,698)		-
Preferred stock dividend	(56,575)		-
Net (loss)		$ (39,004,193)		$ (29,815,661)
Net (Loss) applicable to common stockholders	(29,116,960)		$ (18,783,324)
	Preferred stock dividend	$ (86,980)		$ -
Net (Loss) per share	$ (0.09)		$ (0.11)
	Net (loss) applicable to common stockholders	$ (39,091,173)		$ (29,815,661)
Weighted average number of common shares outstanding – basic and diluted	316,097,089		161,911,391
	Basic and diluted net (loss) per share:
	Continuing operations	$ (0.09)		$ (0.18)
	Discontinued operations	(0.03)		-
	Total basic and diluted net (loss) per share	$ (0.12)		$ (0.18)
	Weighted average number of common shares outstanding – basic and diluted	327,925,252		170,204,573

See accompanying notes to these unaudited condensed consolidated financial statements

HIGH PLAINS GAS, INC.

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOW

FOR THE ~~SIX~~NINE MONTHS ENDED ~~JUNE~~SEPTEMBER 30, 2012 AND 2011

(UNAUDITED)

	For the Six Months ended June 30,
	For the Nine Months ended September 30,
	2012	2011
Cash Flows from Operating Activities:
Net (loss)	$ (2939,~~173~~004,~~535~~193)	$ (1829,~~783~~815,~~324~~661)
Adjustments to reconcile net (loss) to net cash provided by (used) in operating activities:
Adjustments to reconcile net (loss) to net cash provided by (used) in operating activities net of discontinued operations:
Depletion, depreciation and amortization	1,971,347	3,347,365
Depreciation, depletion, amortization, and accretion	2,461,445	5,580,057
Accretion of asset retirement obligation	359,741	388,746
Amortization of bond commitment and finance fees	341,801	2,403,173
Amortization of bond commitment and finance fees	231,954	2,050,538
Abandonment of oil and gas prospect	-	4,127,758
Amortization of debt discount	17	-471,650
Unrealized commodity hedge (gain) / loss	-	28,215
Unrealized commodity hedge loss / (gain)	2,182,401	(1,128,902)
Stock and warrant based compensation	2,~~021~~691,~~778~~932	~~253~~364,~~054~~548
Stock issued for services	313,~~454~~455	~~813~~1,017,004
Stock issued for commitment fee	166,663	-150,644
Impairment of oil and gas prospects	13,440,869	42,~~125~~565,~~010~~270
Impairment of intangible assets	3,604,645	-
Impairment of other assets	240,757	-
Loss on fair value of securities	-	~~893~~2,~~506~~645,108
Loss on conversion of bonding liability	63,646	-
Loss on impairment of intangible assets		-
Loss on debt conversion	145,653	532,932
Loss on extinguishment of debt	63,646	4,856,513
Loss on debt conversion related party	1,080,000	-
Loss on debt conversion	453,567	-
Proceeds from the sale of accounts receivable	5,937,800	-
Loss on debt conversion related party	856,415	-
Repayments of accounts receivable sold	(4,370,054)
Interest added to related party notes payable	-	180,856
Interest added to related party notes payable	-	102,480
Changes in operating assets and liabilities:
Increase / decrease in accounts receivable	683,138	(433,386)
Decrease (Increase) in accounts receivable	1,088,400	(310,259)
Decrease in prepaid and other assets	~~532~~(364,~~084~~403)	85(115,~~402~~007)
Rebates receivable – accounts receivable sales	(276,661)	-
Increase in accounts payables and accrued liabilities	1,695,800	8,810,551
Increase in accounts payables and accrued liabilities	3,768,917	8,166,873
Decrease in assets of discontinued operations	9,914,556	-
Net cash provided by operating activities	501,456	1,570,415
Increase in liabilities of discontinued operations	4,673,158	-
Net cash provided by operating activities	1,216,286	1,803,303
Cash Flows from Investing Activities:
Additions to oil and gas properties	(11,424)	(~~623~~1,~~931~~114,949)
Deposits on acquisition of oil and gas property	-	(2,000,000)
Purchase of equipment	(~~148~~164,~~750~~461)	(~~546~~552,~~839~~864)
Net cash (used in) investing activities	(~~160~~175,~~174~~885)	(3,~~170~~667,~~770~~813)
Cash Flows from Financing Activities:
Proceeds from related party notes payable	-	642,261
Proceeds from notes payable	750,000	-
Repayment of related party notes payable	-	(668,541)
Repayment of notes payable	(780,765)	-
Proceeds from related party notes payable	-	892,261
Repayment of related party notes payable	(100,000)	(695,541)
Proceeds from line of credit	-	75,000
Repayment of line of credit	(~~154~~909,~~830~~744)	(~~118~~379,~~134~~334)
Proceeds from term debt	~~750,000~~-	12,~~885~~110,000
Repayment of term debt	~~(711,263)~~-	(1,~~229~~504,~~387~~580)
Warrants issued for cash	-	1,000,000
Stock issued for cash, net of fees	-	2,054,889
Payment of bond commitment fees	(216,438)	(214,951)
Payment of financing fees	(60,000)	(770,000)
Net cash provided by (used in) financing activities	(~~392~~1,~~531~~316,947)	2,~~656~~567,~~137~~744
Net Increase in Cash and Cash Equivalents	(51276,~~249~~546)	1703,~~055,782~~234
Cash and Equivalents, at beginning of period	~~435~~321,~~015~~227	208,823
Cash and Equivalents, at end of period	$ ~~383~~44,~~766~~681	$ 1912,~~264,605~~057

See accompanying notes to these unaudited condensed consolidated financial statements

HIGH PLAINS GAS, INC.

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOW

FOR THE ~~SIX~~NINE MONTHS ENDED ~~JUNE~~SEPTEMBER 30, 2012 AND 2011 (continued)

(UNAUDITED)

	For the Six Months Ended June 30,
	For the Nine Months Ended September 30,
	2012	2011
Supplemental Cash Information:
Cash paid for interest	$ 324,539	$ ~~883~~539,~~204~~360
Non-cash transactions:
Deposit on acquisition of oil and gas property with stock	$ -	$ 2,125,010
Shares returned to treasury in connection with extinguishment of bonding liabilities	$ (16,000)	$ -
Stock and warrants issued in conversion of related party notes payable	$ 3,780,000	$ 309,573
Warrants issued as compensation	$ -	$ 27,403
Value attributable to Beneficial Conversion Feature	$ 836,000	$ -
Discount on convertible notes recorded to additional paid in capital	$ 836,000	$ -
Common stock issued for settlement of related party debt	$ -	$ 77,001
Common stock issued in connection with prepaid services	$ 438,608	$ -
Preferred stock issued for settlement of related party debt	$ -	$ 969
Common stock issued in connection with settlement of accounts payable	$ 41,511	$ -
Debt forgiveness from related parties	$ -	$ 2,063,022
Debt conversion of related party debt	$ -	$ 4,868,424
Common stock issued for related party note payable repayment	$ -	$ 1,500,000
Common stock issued for commitment fee on securities purchase	$ 166,665	$ -
Discount on convertible notes recorded to additional paid in capital	$ -	$ 734,989
Common stock issued in connection with prepaid services	$ 271,943	$ -
Common stock issued in connection with settlement of accounts payable	$ 41,511	$ 1,131,296
Common stock issued in connection with conversion of notes payable	$ 892,981	$ -
Dividends declared on Series A Convertible Preferred Stock	$ 5686,~~575~~980	$ -
Equipment purchased with debt financing	$ 153,311	$ -
Additions to gas properties included in accounts payable and accrued liabilities	$ 550,034	$ -

See accompanying notes to these unaudited condensed consolidated financial statements

HIGH PLAINS GAS, INC.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

~~June~~September 30, 2012

NOTE 1: ORGANIZATION

High Plains Gas, Inc. (~~“The~~the “Company, “We, “Our”), a Nevada corporation, together with its wholly owned subsidiaries, provides construction services, and repair and maintenance services primarily to the energy and energy related industries primarily located in Wyoming, North Dakota, Montana, Oklahoma and Texas, and as aproduces ~~producer of~~ natural gas in the Powder River Basin in Northeast Wyoming. During our fiscal year ended December 31, 2011, we commenced a strategic shift in operations from primarily natural gas production to a more focused approach towards energy construction services, and repair and maintenance services. During the three months ended June 30, 2012, we shut in our natural gas producing assets. In February 2013, our Energy Construction Services, and ~~have~~Repair noand ~~immediate~~Maintenance ~~plans~~Services todivision ~~resume~~discontinued ~~production~~its operations, coinciding with the disposition of Miller Fabrication, LLC (“Miller”) (Note 5). On March 28, 2013, we executed an Agreement and Plan of Merger between the Corporation and Chama Technologaes, Inc. (“Chama”), a Nevada corporation, for the purchase by Chama of a controlling stock interest in High Plains.

~~NOTE~~The ~~2: BASIS~~terms OFof ~~PRESENTATION~~the ~~AND~~acquisition ~~SIGNIFICANT~~are ~~ACCOUNTING~~substantially ~~POLICIES~~as follows:

~~Basis of Presentation.~~ The ~~accompanying~~Agreement ~~unaudited~~requires ~~financial~~that ~~statements have been prepared in accordance with accounting principles generally accepted in~~ the ~~United~~Company ~~States~~complete ofa ~~America~~1 ~~(“GAAP”)~~ for ~~interim~~1,000 ~~financial~~reverse ~~information~~split ~~and~~of ~~with~~High ~~the~~Plains ~~instructions~~Gas tocommon ~~Form 10-Q~~stock. ~~They~~Upon docompletion ~~not include all~~ of the ~~information~~reverse ~~and~~stock ~~footnotes~~split, ~~required~~we bywill ~~accounting~~have ~~principles~~approximately ~~generally~~305,000 ~~accepted~~shares ~~in the United States~~ of ~~America~~common ~~for~~stock ~~a complete financial presentation~~outstanding. InPursuant to the ~~opinion of management~~merger, ~~all~~we ~~adjustments,~~were ~~consisting~~to ~~only~~issue ofto ~~normal~~Chama ~~recurring~~shareholders ~~adjustments~~25,000,000 ~~considered~~shares ~~necessary for a fair presentation have been included in the accompanying unaudited financial statements. Operating results for the periods presented are not necessarily indicative~~ of ~~the~~High ~~results~~Plains ~~that~~Gas ~~may be expected for the full year~~stock. ~~These~~We ~~financial~~assumed ~~statements~~approximately ~~should~~$4,000,000 ~~be read~~ in ~~conjunction~~obligations ~~with~~owed ~~the~~to ~~financial~~previous ~~statements~~shareholders ~~and footnotes which are included as part~~ of ~~the~~RWM ~~Company’s~~Resources, ~~Form~~Inc. ~~10-K~~an ~~for~~entity ~~the~~that ~~year~~was ~~ended~~previously ~~December~~owed ~~31,~~by ~~2011~~Chama.

~~Liquidity. The Company incurred a net loss of $29,173,535 during the first six months of 2012, has negative working capital of $24,434,463 and an accumulated deficit of $92,479,081.~~ As ~~a result~~ the Company is indelinquent ~~technical default of certain covenants contained~~ in its ~~credit~~filings ~~and loan agreement~~ with ~~its~~the ~~primary lender~~U.S. ~~The~~Securities ~~holder~~and ofExchange ~~the~~Commission ~~promissory~~(“SEC”) ~~note under~~ the ~~credit~~impact ~~and~~of ~~loan~~the merger agreement ~~may~~cannot atbe ~~its~~effectuated ~~option~~through ~~give notice to~~ the ~~Company~~rules ~~that the amount is immediately due~~ and ~~payable.~~regulations ~~As a result, $6.0 million~~ of ~~the~~FINRA ~~Company’s~~and ~~long-term~~consequently ~~debt~~ has not been ~~classified~~effectuated ~~as a current liability~~ in the accompanying unaudited ~~balance~~financial ~~sheet at June 30, 2012~~statements.

~~The~~NOTE ~~Company’s~~2: ~~recurring~~GOING losses and negative working capital raise substantial doubt about the Company’s ability to continue as a going concern. The Company has established certain internal operating and management initiatives which include the curtailment of production related to our gas assets, potential disposal of certain non-performing assets, attempting to raise new capital for future operations and focusing on the recently created Energy Construction Services, and Repair and Maintenance Services division. In addition management will continue to explore other options which may include a change in the Company’s corporate structure. However, there can be no assurance that the Company will be successful in achieving its objectives. CONCERN

~~The~~As ~~unaudited~~of ~~condensed~~September ~~consolidated~~30, ~~financial~~2012 ~~statements~~our docurrent ~~not~~liabilities ~~include~~exceeded ~~any~~our ~~adjustments~~current toassets ~~reflect~~by $29,709,328 and for the ~~possible~~nine ~~future~~months ~~effects~~ended onSeptember ~~the~~30, ~~recoverability~~2012, our net loss from continuing operations was $29,984,495, while our loss from discontinued operations amounted to $9,019,698. Our results of operations have resulted in an accumulated deficit of $102,327,011 and ~~classification~~a total stockholders’ deficit of ~~assets~~$39,389,143 oras of September 30, 2012. We currently have no production related to our natural gas properties and the ~~amounts~~operations related to our Energy Construction Services and ~~classifications~~Repair and Maintenance Division have been discontinued. We have past due debt obligations and a significant amount of current liabilities that ~~may~~are ~~result~~past ~~should~~due. If additional financing is not available and or if we are unable to fund our operating cash flow needs the Company may be unable to continue asto ~~a going concern~~exist.

~~Business~~NOTE ~~Segment Information. The Company is comprised of two operating segments~~3: BASIS ~~(1)~~OF ~~Natural~~PRESENTATION ~~Gas~~AND ~~Production~~SIGNIFICANT ~~and~~ACCOUNTING ~~(2) Energy Construction Services, and Repair and Maintenance Services. The unaudited~~ POLICIES

Basis of Presentation. The accompanying unaudited financial statements have been prepared in accordance with accounting principles generally accepted in the United States of America (“GAAP”) for interim financial information and with the instructions to Form 10-Q. They do not include all of the information and footnotes required by accounting principles generally accepted in the United States of America for a complete financial presentation. In the opinion of management, all adjustments, consisting only of normal recurring adjustments, considered necessary for a fair presentation have been included in

condensed consolidated financial statements include High Plains and its wholly owned subsidiaries, High Plains Gas, LLC, which represents the Natural Gas Production operating segment and HPG Services LLC and Miller Fabrication LLC, which together represent the Energy Construction Services, and Repair and Maintenance services operating segment. All significant intercompany transactions have been eliminated in consolidation. In accordance with FASB Accounting Standards Codification “ASC” 280,”Segment Reporting” the Company has evaluated how it is organized and managed and has identified two operating segments which include (1) the exploration and production of natural gas, and (2) construction and repair and maintenance services for the energy industry. The Company considers its gathering and marketing functions as ancillary to these activities. All of the Company’s operations and assets are located in the United States, and all of its revenues are attributable to United States customers. 9

~~Use of Estimates. The preparation of financial statements in conformity with GAAP requires management to make estimates and assumptions that affect~~ the ~~reported~~accompanying ~~amounts and the disclosure of contingent amounts in our~~ unaudited ~~consolidated~~ financial statements ~~and the accompanying notes~~. Operating ~~Actual~~ results ~~could~~for ~~differ~~the ~~from~~periods ~~those~~presented ~~estimates. The Company’s financial statements~~ are ~~based~~not onnecessarily aindicative ~~number~~ of ~~significant~~the ~~estimates,~~results ~~including: (1)~~that ~~oil~~may ~~and~~be ~~gas~~expected ~~reserve~~for ~~quantities;~~the ~~(2)~~full ~~depletion,~~year. These ~~depreciation~~financial ~~and~~statements ~~amortization;~~should ~~(3)~~be ~~assigning~~read ~~fair value and allocating purchase price~~ in ~~connection~~conjunction with ~~business~~the ~~combinations;~~financial ~~(4)~~statements ~~valuation~~and offootnotes ~~commodity~~which ~~derivative~~are ~~instruments;~~included ~~(5)~~as ~~asset~~part ~~retirement obligations; (6) valuation~~ of ~~share-based~~the ~~payments;~~Company’s ~~(7)~~Form ~~income taxes; (8) cash flow estimates used in impairment tests of long~~10-~~lived~~K ~~assets;~~for ~~and(9)~~the ~~Impairment~~year ofended ~~intangible~~December ~~assets~~31, 2011.

Liquidity. The Company incurred a net loss from continuing operations of $29,984,495 and losses from discontinued operations of $9,019,698 during the first nine months of 2012, had negative working capital of $29,709,328 and an accumulated deficit of $102,327,011. As a result the Company is in technical default of certain covenants contained in its credit and loan agreement with its primary lender. The holder of the promissory note under this credit and loan agreement may at its option give notice to the Company that the amount is immediately due and payable. As a result, $5.3 million of the Company’s long-term debt has been classified as a current liability in the accompanying unaudited balance sheet at September 30, 2012.

The Company’s recurring losses, negative working capital and lack of revenue resulting from the shutting in of its gas producing assets in May 2012 coupled with the discontinued operations of its Energy Construction Services and Repair and Maintenance Services business segment raise substantial doubt about the Company’s ability to continue as a going concern.

The unaudited condensed consolidated financial statements do not include adjustments to reflect the future effects on the recoverability and classification of assets or the amounts and classifications of liabilities that may result should the Company be unable to continue as a going concern.

Business Segment Information. The Company had historically been comprised of two operating segments: (1) Natural Gas Production and (2) Energy Construction Services and Repair and Maintenance Services. The unaudited condensed consolidated financial statements include High Plains and its wholly owned subsidiaries, High Plains Gas, LLC, which represents the Natural Gas Production operating segment and HPG Services LLC and Miller Fabrication LLC, which together represented the Energy Construction Services and Repair and Maintenance services operating segment. As noted elsewhere herein the Company has discontinued the operations of the Energy Constructions Services and Repair and Maintenance Services business segment (Note 5). All significant intercompany transactions have been eliminated in consolidation.

Use of Estimates. The preparation of financial statements in conformity with GAAP requires management to make estimates and assumptions that affect the reported amounts and the disclosure of contingent amounts in our unaudited consolidated financial statements and the accompanying notes. Actual results could differ from those estimates. The Company’s financial statements are based on a number of significant estimates, including: (1) oil and gas reserve quantities; (2) depletion, depreciation and amortization; (3) assigning fair value and allocating purchase price in connection with business combinations; (4) valuation of commodity derivative instruments; (5) asset retirement obligations; (6) valuation of share-based payments; (7) income taxes; (8) cash flow estimates used in impairment tests of long-lived assets; and (9) Impairment of intangible assets.

Revenue Recognition. Revenues related to natural gas sales are under the sales method of accounting. Under this method, revenues are recognized on production as it is taken and delivered to its purchasers.

Revenue from long-term construction contracts for which we use the percentage-of-completion method of accounting. Percentage-of-completion accounting is the prescribed method of accounting for long-term contracts in accordance with Accounting Standards Codification ASC Topic 605-35, “Revenue Recognition – Construction-Type and Production-Type Contracts”, and, accordingly, is the method used for revenue recognition within our industry. Percentage-of-completion is measured principally by the percentage of costs incurred to date for each contract to the estimated total costs for such contract at completion. Certain of our business units may measure percentage-of-completion by the percentage of labor costs incurred to date for each contract to the estimated total labor costs for such contract. Application of percentage-of-completion accounting results in the recognition of costs and estimated earnings in excess of billings on uncompleted contracts in our unaudited consolidated balance sheets. Costs and estimated earnings in excess of billings on uncompleted contracts will be reflected in the unaudited condensed consolidated balance sheets when revenues have been recognized but the amounts cannot be billed under the terms of contracts. Such amounts are recoverable from customers upon various measures of performance, including achievement of certain milestones, completion of specified units or completion of a contract. As of June 30, 2012 we have not recorded any recorded any amounts on a percentage-of-completion basis in our unaudited condensed consolidated financial statements.

11percentage of costs incurred to date for each contract to the estimated total costs for such contract at completion. Certain of our business units may measure percentage-of-completion by the percentage of labor costs incurred to date for each contract to the estimated total labor costs for such contract. Application of percentage-of-completion accounting results in the recognition of costs and estimated earnings in excess of billings on uncompleted contracts in our unaudited consolidated balance sheets. Costs and estimated earnings in excess of billings on uncompleted contracts will be reflected in the unaudited condensed consolidated balance sheets when revenues have been recognized but the amounts cannot be billed under the terms of contracts. Such amounts are recoverable from customers upon various measures of performance, including achievement of certain milestones, completion of specified units or completion of a contract. As of September 30, 2012 we have not recorded any amounts on a percentage-of-completion basis in our unaudited condensed consolidated financial statements.

Costs and estimated earnings in excess of billings on uncompleted contracts also include amounts we seek or will seek to collect from customers or others for errors or changes in contract specifications or design, contract change orders in dispute or unapproved as to both scope and price or other customer-related causes of unanticipated additional contract costs (claims and unapproved change orders). Such amounts are recorded at estimated net realizable value and take into account factors that may affect our ability to bill unbilled revenues and collect amounts after billing. The profit associated with claim amounts is not recognized until the claim has been settled and payment has been received. Due to uncertainties inherent in estimates employed in applying percentage-of-completion accounting, estimates may be revised as project work progresses. Application of percentage-of-completion accounting requires that the impact of revised estimates be reported prospectively in the condensed consolidated financial statements. In addition to revenue recognition for long-term construction contracts, we recognize revenues from the performance of facilities services for maintenance, repair and retrofit work consistent with the performance of services, which are generally on a pro-rata basis over the life of the contractual arrangement. Expenses related to all services arrangements are recognized as incurred. Provisions for the entirety of estimated losses on uncompleted contracts are made in the period in which such losses are determined. As of ~~June~~September 30, 2012 we have not recorded any amounts related to earnings in excess of billings on our unaudited condensed consolidated financial statements.

Reclassifications. Certain account balances from prior periods have been reclassified in these unaudited condensed consolidated financial statements so as to conform to current year classifications.

Recently issued accounting pronouncements. Accounting standards-setting organizations frequently issue new or revised accounting rules. We regularly review all new pronouncements to determine their impact, if any, on our financial statements. No pronouncements materially affecting our financial statements have been issued since the filing of our Form 10-K for the year ended December 31, 2011.

~~Loss~~NOTE ~~per~~4: ~~common~~LOSS ~~share. We~~PER doCOMMON ~~not report fully diluted loss per common share as the effect would be anti-dilutive.~~SHARE

~~NOTE~~Basic ~~3: NATURAL~~net ~~GAS~~income ~~PROPERTIES~~(loss) per common share is computed by dividing the (loss) attributable to common shareholders by the weighted average number of shares of common stock outstanding during the period.

In May 2012 The Company shut in its gas producing assets and ceased production of natural gas. The Company recognized no revenue from gas production in June, 2012 and has no definitive plans to resume production in the foreseeable future.11

Diluted net income (loss) per common share is computed in the same manner, but also considers the effect of common stock shares underlying the following:


	September 30, 2012
Common stock options		85,634,044
Convertible notes payable		62,000,000
Common stock warrants		9,346,806
Total		156,980,850

All of the common shares underlying the stock options, warrants and convertible notes payable above were excluded from diluted weighted average shares outstanding for the nine months ended September 30, 2012 respectively because their effects were considered anti-dilutive.

NOTE 5: DISCOUNTINUED OPERATIONS

On February 20, 2013 the Company completed a purchase and sale agreement whereby Miller Fabrication, LLC (“Miller”) was sold. In connection with the sale of Miller, the Company also determined to discontinue the operations of its Energy Construction Services and Repair and Maintenance Services Division. Results from operations from the Energy Constructions Services and Repair and Maintenance Services division, including Miller for the three and nine months ended September 30, 2012 and 2011 have been presented in our Condensed Consolidated Statement of Operations as discontinued operations.

The components of the result of discontinued operations for these divisions are as follows:


	Three months ended September 30,		Nine months ended September 30,
	2012	2011(a)	2012	2011(a)
Service revenue	$ 2,919,603	$ -	$ 14,958,112	$ -
Cost of services	2,971,616	-	14,508,448	-
General and administrative expenses	54,215	-	426,808	-
Depreciation, depletion, amortization, and accretion	66,110	-	183,258	-
Operating (loss)	$ (172,338)	$ -	$ (160,402)	$ -
Other income (expense)	(31,799)	-	(31,799)	-
Interest (expense)	(149,135)	-	(222,883)	-
Impairment of intangible and other assets	(4,999,969)	-	(8,604,614)	-
Net income (loss)	$ (5,353,241)	$ -	$ (9,019,698)	$ -

(a)

As noted in Note 10, the Energy Construction Services and Repair and Maintenance Services division was formed primarily through the purchase of Miller during the fourth fiscal quarter of 2011 (October 14, 2011, accordingly there is no discontinued operations income statement presentation for the three and nine months ended September 30, 2011 respectively.

Included in Assets and Liabilities of Discontinued Operations the Condensed Consolidated Balance Sheets at September 30, 2012 and December 31, 2011 are the following major classes of assets and liabilities associated with discontinued operations:


	As of
	September 30, 2012	December 31, 2011
Cash and cash equivalents	$ 128,287	$ 113,788
Accounts receivable	1,245,711	2,974,222
Prepaid and other assets	63,593	26,177
Total current assets	1,437,591	3,114,187
Property, plant, and equipment	854,756	1,966,516
Other assets	918,845	7,496,360
Total assets	3,211,192	$ 12,577,063

Accounts payable	$ 5,848,775	$ 1,933,932
Current portion – term debt	205,317	-
Current portion – lines of credit	-	100,500
Notes payable	387,730	628,075
Other liabilities	1,442,528	-
Total current liabilities	7,884,350	2,662,507
Total liabilities	$ 7,884,350	$ 2,662,507

Net (liabilities) assets of discontinued operations	$ (4,673,158)	$ 9,914,556

NOTE 6: NATURAL GAS PROPERTIES

In May 2012, the Company shut in its gas producing assets and ceased production of natural gas. The Company recognized no revenue from gas production from June through September 2012. As of the date of these consolidated financial statements, production has not resumed.

The Company’s gas exploration and production activities are accounted for using the successful efforts method. Under this method, all property acquisition costs and costs of exploratory and development wells are capitalized when incurred, pending determination of whether the well has found proved reserves. If an exploratory well does not find proved reserves, the costs of drilling the well are charged to expense and included within cash flows from investing activities. The costs of development wells are capitalized whether productive or nonproductive. Gas lease acquisition costs are also capitalized. Interest cost is capitalized as a component of property cost for significant exploration and development projects that require greater than six months to be readied for their intended use.

Other exploration costs, including certain geological and geophysical expenses and delay rentals for gas leases, are charged to expense as incurred. The sale of a partial interest in a proved property is accounted for as a cost recovery, and no gain or loss is recognized as long as this treatment does not significantly affect the unit of production amortization rate. A gain or loss is recognized for all other sales of proved properties and is classified in other operating revenues. Maintenance and repairs are charged to expense.

The unit-of-production method of depreciation, depletion, and amortization of gas properties under the successful efforts method of accounting is applied pursuant to the simple multiplication of units produced by the costs per unit on a field by field basis. Leasehold cost per unit is calculated by dividing the total cost by the estimated total proved oil and gas reserves associated with that field. Well cost per unit is calculated by dividing the total cost by the estimated total proved developed oil and gas reserves associated with that field. The volumes or units produced and asset costs are known and while the proved reserves have a high probability of recoverability, they are based on estimates that are subject to some variability. Depletion expense was $466,892 and $863,115 during the three and six months ended June 30, 2012 respectively. During the three and six months ended June 30, 2011 depletion expense was $1,302,066 and $3,202,042 respectively.

1213

associated with that field. The volumes or units produced and asset costs are known and while the proved reserves have a high probability of recoverability, they are based on estimates that are subject to some variability. Depletion expense was $nil and $863,523 during the three and nine months ended September 30, 2012 respectively. During the three and nine months ended September 30, 2011 depletion expense was $1,567,421 and $4,769,663 respectively.

Aggregate Capitalized Costs. Aggregate capitalized costs relating to the Company’s crude oil and natural gas producing activities, including asset retirement costs and related accumulated depreciation, depletion and amortization are as follows:

	Capitalized Costs	Accumulated DD&A and Impairment	Net Capitalized Costs
As of June 30, 2012
As of September 30, 2012
Proved	$ 19,417,440	$ (19,417,440)	$ -
Unproven	9,755,742	(9,755,742)	-
Shut-in	6,378,626	(6,378,626)	-
Asset retirement obligations	8,562,883	(8,562,~~833~~883)	-
Total	$ 44,114,691	$ (44,114,691)	$ -
As of December 31, 2011
Proved	$ 18,855,982	$ (15,981,885)	$ 2,874,097
Unproven	9,755,742	(2,116,744)	7,638,998
Shut-in	6,378,626	(6,378,626)	-
Asset retirement obligations	8,562,883	(5,333,045)	3,~~226~~229,838
Total	$ 43,~~533~~553,233	$ (29,810,300)	$ 13,742,933

Costs incurred in Oil and Gas Activities. Costs incurred in connection with the Company’s crude oil and natural gas acquisition, exploration and development activities for each of the years are shown below:

	June 30, 2012	December 31, 2011
	September 30, 2012	December 31, 2011
Lease acquisition costs	$ 20,914,226	$ 20,914,226
Development costs	14,637,582	14,076,125
Asset retirement costs	8,562,883	8,562,882
Total operations	$ 44,114,691	$ 43,~~533~~553,233

We test for impairment of our properties based on estimates of proved reserves. Proved oil and gas properties are reviewed for impairment whenever events or circumstances indicate that the carrying amount may not be recoverable. We estimate the future undiscounted cash flows of the affected properties to judge the recoverability of the carrying amounts. Initially this analysis is based on proved reserves. However, when we believe that a property contains oil and gas reserves that do not meet the defined parameters of proved reserves, an appropriately risk adjusted amount of these reserves may be included in the impairment evaluation. These reserves are subject to much greater risk of ultimate recovery. An asset would be impaired if the undiscounted cash flows were less than its carrying value. Impairments are measured by the amount by which the carrying value exceeds its fair value.

Unproved oil and gas property costs are transferred to proved oil and gas properties if the properties are subsequently determined to be productive and are assigned proved reserves. Proceeds from sales of partial interests in unproved leases are accounted for as a recovery of cost without recognizing any gain until all costs are recovered. Unproved oil and gas properties are assessed periodically for impairment based on remaining lease terms, drilling results, reservoir performance, commodity price outlooks, future plans to develop acreage and other relevant matters. During the three and six months ended June 30, 2012 and 2011, the Company recognized non-cash impairment charges of $12,953,082 and $13,440,869

1314

until all costs are recovered. Unproved oil and $4gas properties are assessed periodically for impairment based on remaining lease terms,~~125~~ drilling results,~~010~~ ~~and~~reservoir $4performance,~~125~~ commodity price outlooks,~~010,~~ ~~respectively~~future plans to develop acreage and other relevant matters. ~~Impairment~~During ~~charges~~the ~~relate~~three toand nine months ended September 30, 2012 and 2011, the Company’s ~~unevaluated~~recognized ~~leasehold~~non-cash ~~costs,~~impairment ~~shut~~charges inof ~~drilling~~$nil ~~equipment~~and $13,440,869 and ~~evaluated~~$2,565,270 ~~shut~~and in$2,565,270, ~~equipment~~respectively.

Revenue. Revenues from the sale of natural gas are recognized when the product is delivered at a fixed or determinable price, title is transferred, collectability is reasonably assured, and evidenced by a contract. This occurs when oil or gas has been delivered to a pipeline or a tank lifting has occurred. The Company may have an interest with other producers in certain properties, in which case the Company uses the sales method to account for gas imbalances. Under this method, revenue is recorded on the basis of gas actually sold by the Company. In addition, the Company records revenue for its share of gas sold by other owners that cannot be volumetrically balanced in the future due to insufficient remaining reserves. The Company also reduces revenue for other owners’ gas sold by the Company that cannot be volumetrically balanced in the future due to insufficient remaining reserves. The Company’s remaining over-and-under produced gas balancing positions are considered in the Company’s proved oil and gas reserves. Gas imbalances at ~~June~~September 30, 2012 and 2011 were not significant.

NOTE 47: ASSET RETIREMENT OBLIGATION

Asset retirement obligations require the recognition of a liability for certain obligations associated with the retirement of long lived assets. Changes in the Company’s asset retirement obligations were as follows:

	Six Months Ended June 30,
Asset retirement obligations, December 31, 2010	$	8,229,630
	2012		2011
Revisions in estimated liabilities		361,202
Asset retirement obligations, beginning of period	$ 9,320,074		$ 8,229,630
Accretion expense		729,242
Revisions in estimated liabilities	-		-
Asset retirement obligations, December 31, 2011	$	9,320,074
Accretion expense	359,741		388,746
Revisions in estimated liabilities		-
Asset retirement obligations, end of period	$ 9,679,815		$ 8,618,736
Accretion expense		359,741
Asset retirement obligations September 30, 2012	$	9,679,815

~~NOTE~~Accretion ~~5: PROPERTY~~expense ~~AND~~for ~~EQUIPMENT~~the three and nine months ended September 30, 2012 amounted to $nil and $359,741, respectively.

NOTE 8: PROPERTY AND EQUIPMENT

Property and equipment is stated at cost and is depreciated using the straight-line method over estimated useful lives of 5 to 10 years.

	June 30, 2012	December 31, 2011
	September 30, 2012	December 31, 2011
Transportation and vehicles	$ ~~1,314,744~~-	$ ~~1,076,949~~-
Equipment and other	~~1,265,704~~-	~~1,311,161~~-
Computer and software	~~423,069~~-	~~313~~423,~~346~~069
Total Cost	~~3,003,517~~-	2423,~~701,456~~069
Accumulated depreciation	~~(711,897)~~-	(~~408~~96,~~164~~293)
Property and equipment, net	$ ~~2,291,620~~-	$ 2326,~~293,292~~776

Depreciation expense was $161,306, and $303,733, and $104,778 and $145,119, during the three and six months ended June 30, 2012 and 2011, respectively.

NOTE 6: CERTIFICATES OF DEPOSIT

The Company maintains certificates of deposits that have been established for the purpose of operations in the state of Wyoming. At June 30, 2012 and December 31, 2011, the outstanding amount totaled $201,988 and $201,988, respectively.

~~NOTE~~Depreciation ~~7: ACQUISITIONS~~expense ~~AND~~was ~~DISPOSITIONS~~$93,100, and $280,002, and $104,956 and $250,075, during the three and nine months ended September 30, 2012 and 2011, respectively.

During the three month period ended September 30, 2012, the Company recorded impairment of property and equipment of $240,757. The impairment was recorded pursuant to the Company’s decision in May 2012 to shut in all of its gas producing assets and ceased production of natural gas. The Company recognized no revenue from gas production subsequent to shut in and has no definitive plans to resume production in the foreseeable future. As of September 30, 2012 and December 31, 2011, $854,756 and $1,966,516 in property and equipment have been included as components of Assets of Discontinued Operations in our Consolidated Balance Sheets.

NOTE 9: CERTIFICATES OF DEPOSIT

The Company maintains certificates of deposits that have been established for the purpose of operations in the state of Wyoming. At September 30, 2012 and December 31, 2011, the outstanding amount totaled $nil and $201,988, respectively.

NOTE 10: ACQUISITIONS AND DISPOSITIONS

Business Combinations

Miller Fabrication, LLC: On October 14, 2011, the Company entered into a purchase and sale agreement with Miller Fabrication, LLC, a Douglas, Wyoming-based facility construction services and repair and maintenance services company serving the energy industry, for total consideration of $845,000 in cash consideration, $3,000,000 in a short term note payable, $3,000,000 in a long term note payable, and 12,000,000 options to purchase High Plains common shares. The effective date of the transaction was October 1, 2011. On March 29, 2012, the Board of Directors approved an amendment to the notes payable to reflect a conversion price of $0.05 per share for $2,700,000 in principal and the conversion of said principal into 54,000,000 shares of common stock. Notes 12 and 14 provide additional information about the conversion.

The following table summarizes the final purchase accounting for the fair value of the assets acquired and liabilities assumed at the date of the acquisition:


	Allocated Fair Value
Current assets	$ 1,813,940
Property and equipment	633,278
Employment agreements	2,142,812
Customer relationships	5,716,694
Total assets acquired	$ 10,306,724
Total liabilities assumed	1,319,092
Net assets acquired	$ 8,987,632

The excess of the consideration paid and liabilities assumed has been allocated to intangible assets of $5,716,694 as customer lists and relationships which are estimated to have a useful life of 5 years as well as $2,142,812 related to employment agreements. The value of the employment agreements was derived from the fair value of the vested portion of stock options issued to the principals of the acquired entity in connection with the execution of the employment agreements.

~~During the three months ended June 30, 2012 we recorded impairment charges of $3,593,365 against customer lists and relationships and $11,280 against employment agreements (Note 8).~~16

Asset Purchases

BGM Buildings, LLC: On November 2, 2011 the Company acquired certain assets and liabilities of BGM Buildings, LLC (“BGM”) for 2,000,000 shares of common stock and cash consideration in the form of a $55,000 note payable bearing 0% interest due and payable on November 8, 2011. This note was repaid on November 18, 2011.

16NOTE 11: INTANGIBLE ASSETS

17The components of identifiable intangible assets as of September 30, 2012 are as follows:

NOTE 8: INTANGIBLE ASSETS


	Gross Carrying Amount	Accumulated Amortization	Discontinued Operations	Net Carrying Value
Intangible Assets:
Customer Relationships	5,716,694	(920,838)	(4,795,856)	-
Employment Agreements	2,154,092	(412,491)	(1,741,601)	-

Total	7,870,786	(1,333,329)	(6,537,457)	-

~~The~~Amortization ~~components~~expense offor ~~identifiable~~ intangible assets aswas of$154,254 ~~June~~and $958,903 for the three and nine months ended September 30, 2012, ~~are~~respectively, aswith ~~follows:~~ no comparable expense in 2011.

	Gross Carrying Amount	Accumulated Amortization	Impairment	Net Carrying Amount	Weighted Average Useful Life (Years)
Intangible Assets:
Customer Relationships	$ 5,716,694	($857,653)	($3,593,365)	$ 1,265,676	5
Employment Agreements	2,154,092	(321,422)	(11,280)	1,821,390	5
Total	$ 7,870,786	($1,179,075)	($3,604,645)	$ 3,087,066	5

During the three and nine months ended September 30, 2012, remaining unamortized intangible assets have written down to a carrying value of $0 as a component of losses incurred in connection with discontinued operations as described elsewhere herein.

~~Amortization~~NOTE ~~expense~~12: SHAREHOLDERS’ ~~for intangible assets was $392,975 and $804,499 for the three and six months ended June 30, 2012, respectively, with no comparable expense in 2011.~~EQUITY

During the three and six months ended June 30, 2012 impairment expense related to intangible assets amounted to $3,604,645 and $3,604,645 respectively. We recorded no impairment expense related to intangible assets during the corresponding 2011 periods. Impairment expense recorded during the three months ended June 30, 2012 related to the impairment of customer relationships acquired through our acquisition of Miller Fabrication (Note 7) and impairment of employment agreements related to various agreements executed in fiscal year 2011. The Company’s evaluation of the intangible asset indicated that due to decreases in revenue and reduced contribution to gross margin the underlying assets were impaired.

Expected future intangible asset amortization as of June 30, 2012 is as follows:

Fiscal Year:
2012	$	340,866
2013		681,727
2014		681,727
2015		681,727
2016		574,587
Thereafter		126,432
Total	$	3,087,066

NOTE 9: SHAREHOLDERS’ EQUITY

Common Stock

As of ~~June~~September 30, 2012 and December 31, 2011, there were 500,000,000 shares of our $0.001 par value common stock authorized. The Company increased its common stock authorization to 350,000,000 shares during the second quarter of fiscal year ended December 31, 2011. During the third quarter of the 2011 fiscal period, the Company further increased the authorization to 500,000,000 shares. As of ~~June~~September 30, 2012 and December 31, 2011, 353,239,076 and 275,714,410 shares of common stock were outstanding, respectively.

18During the nine months ended September 30, 2012, the Company issued 77,524,666 shares of its common stock as follows:

2012 and December 31, 2011, 348,812,512 and 275,714,410 shares common stock were outstanding, respectively.

During the six months ended June 30, 2012, the Company issued 73,098,102 shares of its common stock, net of shares returned to treasury, as follows:

1,787,566 shares of common stock were issued to external service providers for services rendered at values between $0.04 and $0.15 per share based on quoted market values on the date of issuance.

3,000,000 shares of common stock were issued to a related party for services rendered as follows; 1,000,000 at $0.08 per share and 2,000,000 at $0.04 per share based on quoted market values on the date of issuance.

54,000,000 share of common stock were issued to related parties at $0.0705 per share in association with the conversion of certain promissory notes. Shares were not issued pursuant to the original terms of the convertible note agreements, ~~which~~resulting ~~generated~~in a loss on conversion of debt of $1,080,000.

1217,~~683~~110,~~665~~229 shares of common stock were issued at market values between $0.0301 and $0.07 per share in association with the conversion of certain promissory notes,. The conversion of the promissory notes occurred at conversion terms which ~~generated~~varied afrom ~~loss~~the initial note agreements which generated losses on the conversion of debt of $~~216~~249,~~655~~682.

2,426,871 shares of common stock were issued at $0.07 in association with services provided related to a stock purchase agreement.

(800,000) shares of common stock were returned to treasury in association with the relief of an existing bonding liability. InThe ~~connection~~return ~~therewith~~of athe ~~loss~~shares ofaccounted ~~$63,746~~for ~~has~~under ~~been~~the ~~recognized.~~cost method

Preferred Stock

As of ~~June~~September 30, 2012 we had two classes of preferred shares; Preferred shares $0.001 par value 20,000,000 authorized, no shares issued and outstanding as of June 30, 2012 and December 31, 2011. Series A Convertible Preferred stock, par value $1,000. These shares have no voting rights the total number of shares authorized is 2,500. The shares will pay dividends in cash or in shares of the Company’s common stock at $8.34 per share per month. In the case of non-payment of Preferred dividends a default rate of $15 per share per month will be accrued on all outstanding preferred shares. As of June 30, 2012 and December 31, 2011 there were 810.971 preferred shares issued and outstanding. Dividends totaling $77,148have been accrued as payable to preferred shareholders as of June 30, 2012.:

~~NOTE 10: SHARE BASED COMPENSATION~~·

Preferred shares $0.001 par value 20,000,000 authorized, no shares issued and outstanding as of September 30, 2012 and December 31, 2011;

Series A Preferred stock, par value $1,000. These shares have no voting rights the total number of shares authorized is 2,500. The shares will pay dividends in cash or in shares of the Company’s common stock at $8.34 per share per month. In the case of non-payment of preferred dividends a default rate of $15 per share per month will be accrued on all outstanding preferred shares. As of September 30, 2012 and December 31, 2011, there were 810.971 preferred shares issued and outstanding. Dividends totaling $107,553 have been accrued as payable to preferred shareholders as of September 30, 2012. Each share of Series A Convertible Preferred Stock shall be convertible at any time by the holder thereof into shares of Common Stock of the Company at a conversion price for each share of Common Stock equal to the lower of (i) 80% of the 30 day volume weighted average price (“VWAP”) on the trading day immediately preceding conversion, (ii) 80% of the 10 day VWAP on the trading day immediately preceding conversion or (iii) $.25 per share, but in no case shall the conversion price be less than $.25 per share.

NOTE 13: SHARE BASED COMPENSATION

Common Stock Options

During the ~~six~~nine months ended ~~June~~September 30, 2012, our board of directors approved the grant of 4,834,044 options to employees and external consultants. During the twelve months ended December 31, 2011, our board of directors approved the grant of 81,000,000 options to directors and former directors of the Company, ~~Our~~our former Chief Executive Officer, and the principals of Miller Fabrication LLC in relation to the Company’s acquisition of Miller and the principals’ employment roles at the Company. No options were granted prior to January 1, 2011. Additionally, during the fourth quarter of 2011, the board of directors approved a reduction in the exercise price of the options previously granted to the directors and former directors of the company from $1.02 to $0.05. The 81,000,000 options granted to directors and former directors expired subsequent to the end of the reporting period in accordance with the initial terms of the options which indicates that option grants terminate 90 days from an employee or directors separation from the Company.

1918

A summary of the activity through ~~June~~September 30, 2012 is as follows:

	Number of Shares	Weighted Avg. Exercise Price (1)
Options outstanding - December 31, 2010	-	-
Granted during period	81,000,000	$ 0.10
Exercised during period	-	-
Forfeited during period	(160,000)	$ 1.02
Expired during period	-	-
Options outstanding - December 31, 2011	80,840,000	$ 0.09
Options exercisable – December 31, 2011	16,200,000	$ 0.09
Granted during period	4,834,044	$ 0.09
Exercised during period	-	-
Forfeited during period	-	-
Expired during period	(40,000)	$ 1.02
Options outstanding – June 30, 2012	85,634,044	$0.09
Options outstanding – September 30, 2012	85,634,044	$ 0.09
Options exercisable – June 30, 2012	17,286,809	$0.09
Options exercisable – September 30, 2012	17,286,809	$ 0.09

(1)

Reflects the adjusted exercise price of the options issued to the board members and former board members

In computing the share based compensation expense, the Company applied fair value accounting for stock option issuances. The fair value of each stock option granted is estimated on the date of issuance using the Black-Scholes option-pricing model. Due to the re-pricing of certain stock options, the Company, in accordance with ASC 718-20-55, recalculated the fair value of each stock option granted in order to determine additional share based compensation expense associated with the vested and unvested portion of each option grant. The Black-Scholes assumptions used are as follows:


Exercise Price – Original Price	$0.05 - $1.02
Exercise Price – Adjusted Price	$0.05 - $0.11
Dividend Yield	0%
Volatility	143.7% - 144.21%
Risk-free interest rate	0.87% - 1.17%
Expected life of options	4 years
Expected forfeitures	0%

During the ~~six~~nine months ended ~~June~~September 30, 2012 and ~~2011the~~2011, the Company recognized $12,~~499~~169,~~450~~604 and $nil in share-based compensation respectively related to these issuances. As of ~~June~~September 30, 2012, there was $8,~~946~~276,~~269~~116 in deferred share-based compensation expense related to the unvested portion of the options.

2019

Warrants

During the ~~six~~nine months ended ~~June~~September 30, 2012, the Company issued 4,180,000 warrants in connection with a debt financing. During the twelve months ended December 31, 2011, the Company issued a total of 1,839,679 stock purchase warrants of which 750,000 were issued to employees as compensation with the remainder issued for cash or in association with debt agreements.

A summary of the activity through ~~June~~September 30, 2012 is as follows:

	Number of Shares	Weighted Average Exercise Price
Warrants outstanding - December 31, 2010	5,289,627	$ 0.50
Warrants exercisable - December 31, 2010	5,289,627	$ 0.50
Granted during period	1,839,679	$ 0.53
Exercised during period	-	-
Forfeited during period	(1,500,000)	$ 0.50
Expired during period	-	-
Warrants outstanding - December 31, 2011	5,629,306	$ 0.51
Warrants exercisable - December 31, 2011	5,179,306	$ 0.51
Granted during period	4,180,000	$ 0.10
Exercised during period	-	-
Forfeited during period	(~~250~~462,~~000~~500)	$ 0.50
Expired during period	-	-
Warrants outstanding – June 30, 2012	9,559,306	$0.33
Warrants outstanding – September 30, 2012	9,346,806	$ 0.33
Warrants exercisable – June 30, 2012	9,399,306	$0.33
Warrants exercisable – September 30, 2012	9,346,806	$ 0.33

In computing share based compensation expense, the Company applied fair value accounting for stock warrant issuances. The fair value of each stock option granted is estimated on the date of issuance using the Black-Scholes option-pricing model. The Black-Scholes assumptions used are as follows:


Exercise Price	$0.10 - $1.25
Dividend Yield	0%
Volatility	90% – 175%
Risk-free interest rate	0.90% - 1.31%
Expected life of warrants	1 – 5 years
Expected forfeitures	0%

During the ~~six~~nine months ended ~~June~~September 30, 2012 and 2011, we recognized $522,328 and $~~nil~~29,968 in stock based compensation respectively related to warrants issued to employees. As of ~~June~~September 30, 2012, there was $nil in deferred share based compensation expenses related to the unvested portion of the warrants.

2220

At ~~June~~September 30, 2012, the total intrinsic value of warrants outstanding and exercisable was $nil and $nil, respectively. At December 31, 2011, the total intrinsic value of warrants outstanding and exercisable was $nil and $nil, respectively.

NOTE 1114: DEBT

Letters of Credit

The Company entered into a line of credit agreement with First National Bank of Gillette on November 12, 2010 to provide letters of credit to various agencies and entities for the bonding required to operate the Company’s methane wells. These letters of credit totaled $7,839,358, and any outstanding balances carry an interest rate of 1% over the U.S. Bank Denver Prime Rate. On April 15, 2011, the Company entered into an agreement with Zurich North America to provide fifty percent coverage on the outstanding bonding requirements. The letters of credit were subsequently reduced to $3,928,773. Any outstanding amounts and related interests are due on demand. The agreement is secured by the right of setoff against corporate depository account balances, a mortgage on certain real property, all improvements and equipment on certain well sites and including rights to future production, assignment of a life insurance policy on the Chief Operating Officer as well as personal guarantees of certain shareholders. There were no amounts outstanding on this agreement as of ~~June~~September 30, 2012 and December 31, 2011.

Lines of Credit

A summary of lines of credit outstanding is as follows:

	June 30, 2012	December 31, 2011
	September 30, 2012	December 31, 2011
Current Portion
Amegy Bank (a)	$ 65,~~000~~232,~~000~~830	$ 6,000,000
First National Bank of Gillette (b)	~~102~~82,~~786~~864	225,439
Bank of the West Reserve (c)	--	15,124
Total Lines of Credit Current Portion	$ 5,315,694	$ 6,225,439
Total Lines of Credit Current Portion	$ 6,102,786	$ 6,240,563

All amounts related to our lines of credit have been classified as current liabilities on our consolidated balance sheet as the result of covenant violations.

(a)

On November 19, 2010, the Company (through its wholly owned subsidiary CEP-M Purchase LLC) entered into a line of credit facility with Amegy Bank National Association (“Amegy”) for a revolving line of credit of up to $75,000,000. The facility is to be used to finance up to 60% of the Company’s oil and gas acquisitions, subject to approval by Amegy. The interest rate is based on LIBOR, the amount of the credit facility in use and other factors to determine the prevailing rate on outstanding principal balances (effective rate of 6.25% as of ~~June~~September 30, 2012). Outstanding principal balances and any related accrued interest iswas due on September 17, 2013 subject to mandatory prepayment terms per the agreement. The credit facility is secured by all assets of CEP-M Purchase LLC a mortgage on all proved and possible reserves as well as related well and gathering equipment. As of ~~June~~September 30, 2012, the outstanding principal balance was $65,~~000~~232,~~000~~830. ~~The~~This ~~credit~~amount ~~facility~~remains isoutstanding ~~subject~~and topast ~~restrictive~~due. ~~covenants,~~During ~~and~~the asthree ofmonths ~~June~~ended September 30, 2012 ~~and~~the ~~December~~principal ~~31,~~balance ~~2011,~~of the ~~Company~~note was ~~not~~reduced by $767,170 in ~~compliance~~connection with ~~certain~~the ~~covenants~~execution ~~including~~of ~~but~~a ~~not~~transaction, ~~limited~~termination ~~to:~~and ~~current~~liquidation ~~ratio,~~agreement ~~leverage~~whereby ~~ratio~~its ~~and~~hedging ~~interest~~arrangement ~~coverage~~was ~~ratio~~terminated. ~~The~~(Note ~~outstanding~~16) ~~balance~~As ona ~~the~~component ~~line~~ of ~~credit~~the ~~has~~transaction ~~been~~and ~~classified~~termination asagreement aAmegy ~~current~~received ~~liability~~cash asproceeds ofdirectly ~~June~~from ~~30,~~the ~~2012~~hedge ~~and~~which ~~December~~were ~~31,~~credited ~~2011due~~ to the ~~failure to maintain compliance with these covenants.~~

2321

outstanding principal balance. In connection therewith we recorded a realized loss on the settlement of the hedge in the amount of ($113,248).

The credit facility is subject to restrictive covenants, and as of September 30, 2012 and December 31, 2011, the Company was not in compliance with certain covenants including but not limited to: current ratio, leverage ratio and interest coverage ratio. The outstanding balance on the line of credit has been classified as a current liability as of September 30, 2012 and December 31, 2011 due to the failure to maintain compliance with these covenants.

(b)

On November 29, 2010, the Company entered into an agreement with First National Bank of Gillette for a line of credit of up to $461,148. The line of credit bears an interest rate of 6% and is secured by the right of offset against corporate depository account balances. Terms include the requirement of a monthly payment of $20,400 and the principal becomes due on November 30, 2012. The outstanding balance on this line of credit as of ~~June~~September 30, 2012 was $~~102~~82,~~786~~864. This amount remains outstanding and past due.

(c)

Through the acquisition of Miller Fabrication, LLC the company assumed a $15,124 line of credit that bore interest at 9.25% per annum and was scheduled to mature on September 5, 2012. The line of credit was repaid during the first fiscal quarter of 2012 resulting in an outstanding balance $0 as of June 30, 2012 related to this facility.

Term Debt

A summary of term debt is as follows:

	June 30, 2012	December 31, 2011
	September 30, 2012	December 31, 2011
Current Portion
US Bank (a)	$ ~~590~~546,~~407~~887	$ 659,107
Ford Motor Credit (b)	823,~~761~~675	9,325
Term Notes Various (d)	1,020,463	885,000
Trade Term Notes Various (c)	932,746	910,000
Trade Term Notes Various (e)	178,200	336,377
Total Current Portion	1,503,308	1,578,432
Total Current Portion	1,797,831	1,889,809
Debt Discount (c)	(835,893)	-
Debt Discount (d)	(835,983)	-
Current Portion, net	$ 667,415	$ 1,578,432
Current Portion, net	$ 961,848	$ 1,889,809
Related Party
Term Notes Related Party (f)	$ 393,950	$ 423,837
Term Notes Related Party (e)	$ 393,949	$ 398,838
Miller Group (c)	1,200,000	3,000,000
Miller Group (d)	3,000,000	3,000,000
Total Current Portion Related Party	$ 13,~~593~~393,~~950~~949	$ 3,~~423~~398,~~837~~838
Long Term Portion
US Bank (a)	$ -	$ 16,~~935~~846
Ford Motor Credit (b)	~~17,142~~-	20,~~642~~641
Term Notes Various (d)	11,000	-
Total Long Term Portion	$ -	$ 37,487
Trade Term Notes Various (e)	343,756	377,074
Total Long Term Portion	$ 371,898	$ 414,651
Related Party
Miller Group (c)	~~1,900,000~~-	3,000,000
Total Long Term Portion Related Party	$ ~~1,900,000~~-	$ 3,000,000
Total Term Debt	$ 4,~~827~~061,~~696~~364	$ 8,~~728~~014,~~297~~757

Outstanding balances on term notes and related party notes are due:

2012	$	24,~~858~~061,~~188~~364
2013		~~2,514,742~~-
2014		~~151,496~~-
2015		~~77,416~~-
2016		~~58,903~~-
2017		~~2,934~~-
Total	$	54,~~663~~061,~~679~~364

(a)

On January 20, 2010, the Company entered into a term loan agreement with U.S. Bank of $1,200,000 with a maturity date of January 20, 2013. Payments are due monthly of $16,935 which include interest at 4.95% per annum. The agreement is secured by the right of offset against corporate depository accounts and is guaranteed by certain shareholders. This note is past due and remains outstanding.

(b)

On March 11, 2010, the Company entered into a term loan agreement with Ford Motor Credit of $42,820 with a maturity date of March 31, 2015. Payments are due monthly of $871 which include interest at 7.99% per annum. The agreement is secured by a corporate vehicle. This note is past due and remains outstanding.

(c)

On November 18, 2011 the Company issued two $3,000,000 notes payable to related parties in connection with the acquisition of Miller Fabrication. The notes bear interest at 0% and are due and payable on November 1, 2012 and November 1, 2013 respectively. The notes are convertible into shares of the Company’s common stock at a rate of 70% of the volume weighted average closing price of the Company’s common stock for the twenty days immediately preceding the conversion but not less than $0.30 per share and not more than $2.00 per share. Subsequent to December 31, 2011 the Company agreed to amend the Convertible Promissory Notes. The amendments reduced the conversion price to $0.05 for up to $2,700,000 of the original $6,000,000 in principal. Additionally, the Company amended the repayment terms of the notes. Subsequent to these amendments, principal related party exercised the amended conversion option whereby he converted $1,500,000 in principal into 30,000,000 shares of common stock, and a second related party converted $1,200,000 in principal into 24,000,000 shares of common stock. During the second quarter of 2012, certain related parties received $200,000 in cash payments towards the current portion of these notes. As of June 30, 2012 the outstanding balances on the two notes payable amount to $100,000 which has been classified as short term and $1,900,000 which has been classified as long term on our unaudited consolidated balance sheet.

(d)

Between April 2011 and March 2012, the Company entered into various term loan agreements. Included in various term notes were:

$735,000 of convertible notes payable issued in April and May, 2011. The notes bear interest of 15% per annum and matured on December 31, 2011. The initial terms of the notes allowed for conversion into shares of our common stock at $0.50 per share. Due to the conversion options, the Company recorded debt discounts totaling $734,989. The debt discount was fully accreted as of December 31, 2011. Prior to ~~June~~September 30, 2012, all but one of the convertible notes in the amount of $710,000 plus accrued interest and penalties were converted into 10,883,665 shares of common stock. Prior to the conversion, our board of directors approved for the conversion price to be reduced to between $0.0375 and $0.07 per share. The Company recognized losses of $172,118 as a result of the conversions.

As of ~~June~~September 30, 2012 $25,000 in principal remains outstanding related to the one convertible note still outstanding.

A $100,000 convertible promissory note was originated in October 2011. The note bears interest at 7% and maturing on October 4, 2012. The Note is convertible at a maximum rate of $25,000 every 30 days, into shares of the Company’s common stock based on 70% of the lowest two trading days VWAP, as defined in the terms of the agreement, for the five trading days prior to conversion. As of ~~June~~September 30, 2012 $5410,463 in principal remains outstanding related to this note. Two conversions related to this note were recorded during the quarter ended ~~June~~September 30, 2012. A a total of $45,537 in principal and $5,463 were converted into 1,800,000 shares of our common stock. We recorded losses in the amount of $37,181 during the quarter ended September 30, 2012 in connection with the conversions.

25Two additional notes payable, totaling $200,000 issued in August 2011 with maturities of July through September 2011. Remaining principal balances as of September 30, 2012 and December 31, 2011 were $60,000 and $60,000 respectively. The remaining principal balance is past due, the notes payable bear interest at 0% per annum and are unsecured.

~~We recorded losses in the amount of $37,181 during the quarter ended June 30, 2012 in connection with the conversions.~~23

~~Two~~A ~~additional~~secured ~~notes~~convertible ~~payable,~~promissory note totaling $~~200~~836,000 issued on March 9, 2012 maturing in ~~August~~September ~~2011~~2013 ~~with~~and ~~maturities~~bearing ofinterest ~~July~~at ~~through~~6% ~~September~~per ~~2011~~annum. Payments ~~Remaining~~of ~~principal~~the ~~balances~~greater of $25103,~~000~~125 ~~and~~or 1/8th of the principal balance plus accrued interest were due monthly beginning in September 2012. Due to the conversion features contained in the note, the Company recorded a debt discount totaling $90836,000. The ~~are~~note ~~past~~was ~~due,~~convertible ~~notes~~into ~~payable~~shares ~~bear~~of ~~interest~~the Company’s common stock at $0%.05 per ~~annum~~share. ~~and~~During ~~are~~the ~~unsecured~~nine months ended September 30, 2012, accretion of the debt discount was $17. Conversion

A secured convertible promissory note totaling $836,000 issued in March 2012 maturing in September 2013 and bearing interest at 6% per annum. Payments of the greater of $103,125 or 1/8th of the principal balance plus accrued interest are due monthly beginning in September 2012. Due to the conversion options, the Company recorded a debt discount totaling $836,000. During the six months ended June 30, 2012, accretion of the debt discount was $17. (d)

On November 18, 2011 the Company issued two $3,000,000 notes payable to related parties in connection with the acquisition of Miller Fabrication. The notes bear interest at 0% and are due and payable on November 1, 2012 and November 1, 2013 respectively. The notes are convertible into shares of the Company’s common stock at a rate of 70% of the volume weighted average closing price of the Company’s common stock for the twenty days immediately preceding the conversion but not less than $0.30 per share and not more than $2.00 per share. Subsequent to December 31, 2011 the Company agreed to amend the Convertible Promissory Notes. The amendments reduced the conversion price to $0.05 for up to $2,700,000 of the original $6,000,000 in principal. Additionally, the Company amended the repayment terms of the notes. Subsequent to these amendments, principal related party exercised the amended conversion option whereby he converted $1,500,000 in principal into 30,000,000 shares of common stock, and a second related party converted $1,200,000 in principal into 24,000,000 shares of common stock. During the second quarter of 2012, certain related parties received $200,000 in cash payments towards the current portion of these notes. During the three months ended September 30, 2012 an additional cash payment of $100,000 was made, the remaining $3,000,000 is payable on November 1, 2013. This note is past due and remains outstanding.

(e)

~~Between~~A ~~October~~total ~~2011~~of $393,949 and ~~February~~$423,837 ~~2012~~was owed to various related parties as of September 30, ~~the~~2012 ~~Company~~and ~~acquired~~December or31, ~~entered~~2011, ~~into~~respectively. ~~various~~Included ~~term~~in ~~note~~these ~~agreements~~related ~~including:~~party notes are;

Notes acquired by The Company through its acquisition of Miller Fabrication. The notes were originated on various dates ranging from May 3, 2010 to November 1, 2011. The notes bear interest from 0% to 7.95% per annum and have various maturities ranging from July 2012 through October 2016.

Four notes originated in February 2012. The notes bear interest at 6.8% per annum and mature in February 2017.

(f)

A total of $393,950 and $423,837 was owed to various related parties as of June 30, 2012 and December 31, 2011, respectively. Included in these related party notes are;

A note payable in the amount of $135,~~683~~682 bearing interest at 15% per annum. This note is past due and payable to Mike Hettinger a shareholder of the Company as of ~~June~~September 30, 2012.

A note payable in the amount of $61,027 bearing interest at 0% per annum. This note is past due and payable to Jerri Hettinger a shareholder of the Company as of ~~June~~September 30, 2012

A note payable in the amount of $122,240 per annum bearing interest at 0% due and payable to Mark Hettinger a shareholder and former director of the Company as of December 31, 2012.

A note payable in the amount of $50,000 bearing interest at 10%. This note is past due as and payable to Joe Hettinger a shareholder and former director of ~~June~~the Company as of September 30, 2012.

A note payable in the amount of $25,000 bearing interest at 0% per annum. This note is past due and payable to a shareholder of the Company as of ~~June~~September 30, 2012.

~~NOTE 12: OTHER FINANCING ARRANGEMENTS~~24

~~During~~NOTE the fourth quarter of 2011, Miller Fabrication LLC, a wholly owned subsidiary of the Company, entered into an accounts receivable financing agreement with Amegy Bank National Association (“Amegy”). Under the terms of the agreement the Miller Fabrication, LLC can sell, transfer and assign its rights to certain Miller receivables to Amegy. Immediately upon transfer of the receivables, the Miller Fabrication, LLC receives 85% of the receivable balance. Upon collection of the receivable by Amegy, Miller Fabrication, LLC receives the remaining 15~~% less fees.~~: AsRELATED ofPARTY ~~June 30, 2012, the Miller~~ TRANSACTIONS

26During the nine months ended September 30, 2012, the Company had the following transactions with related parties:

Fabrication, LLC had recorded a receivable related to accounts receivable sold to Amegy in the amount of $276,661 in connection with this arrangement. The sale agreement allows for Amegy to resell back to the Miller Fabrication, LLC any uncollected receivable that is greater than 90 days in age or otherwise deemed to be defective. As of June 30, 2012 $1,844,407 in accounts receivable remained eligible for re-purchase by Miller Fabrication, LLC.

NOTE 13: RELATED PARTY TRANSACTIONS

During the six months ended June 30, 2012, the Company had the following transactions with related parties:

The Company leases real estate property from a related party. Rent expense recognized in connection with this entity for the ~~six~~nine months ended ~~June~~September 30, 2012 totaled $~~318~~434,000 and $176,000 for the year ended December 31, 2011. AsOn ofSeptember ~~June 30~~19, 2012 a lease terminating agreement between the Company and the related party was executed terminating the lease for the Company’s headquarters in Gillette, Wyoming. In connection with the termination of the lease agreement the Company recognized additional rent expense of $58202,000 ~~remains~~as inthe ~~accounts~~result ~~payable~~of the reversal of a previously unrecognized deferred rental liability.

During the ~~six~~nine months ended ~~June~~September 30, 2012, the Company incurred legal fees from a related party totaling $106,357, which had been paid in full as of ~~June~~September 30, 2012. Additionally, as of ~~June~~September 30, 2012, the Company recorded prepaid legal fees to the same related party in the amount of $53,643.

During the ~~six~~nine months ended ~~June~~September 30, 2012, the Company incurred expenses related to the Board of Directors totaling $22,947, of which $352 remain in accounts payable as of ~~June~~September 30, 2012.

In addition to the specific expenses outlined directly above and during the normal course of business, certain related parties procure goods and/or services on behalf of the Company. During the ~~six~~nine months ended ~~June~~September 30, 2012, these expenses totaled $144,831, of which $13,467 remains in accounts payable as of ~~June~~September 30, 2012.

Notes 12 and 14 provide additional detail related to certain equity and debt transactions between the Company and related parties

NOTE 1416: ~~SEGMENT~~INCOME ~~REPORTING~~TAXES

InIncome ~~accordance with ASC 280, the Company has evaluated how it is managed by its chief operating decisions makers and how resources are allocated across the Company~~Taxes. ~~Based~~The ~~on this evaluation, the~~ Company has ~~identified~~analyzed ~~two~~filing ~~reportable~~positions ~~operating~~in ~~segments~~all ~~which~~of ~~are (1) Natural Gas Production segment and (2)~~ the ~~energy~~federal ~~construction~~ and ~~maintenance~~state ~~services~~jurisdictions ~~segment. The~~where ~~Company~~it ~~considers~~is ~~its~~required ~~gathering and marketing functions as ancillary~~ to ~~the~~file ~~natural~~income ~~gas~~tax ~~activities~~returns, ~~and~~as ~~thus~~well ~~they~~as doall ~~not~~open ~~collectively~~tax ~~form~~years ain ~~reportable~~these ~~operating segment~~jurisdictions. ~~All~~No ofuncertain ~~the~~tax ~~Company’s~~positions ~~operations~~have ~~and~~been ~~assets~~identified ~~are~~as ~~located~~of inSeptember ~~the United States~~30, ~~and all of its revenues are attributable to United States customers~~2012.

The Natural Gas Properties segment consists of all activities related to the exploration and production of natural gas, while the energy construction, repair and maintenance services segment consists of all activities related to the construction of equipment and providing of services to the energy industry.

The table below reflects sales and other financial information by business segment as of and for the six months ended June 30, 2012. No comparable information is presented as of and for the six months ended June 30, 2011, as the Company had only one reportable segment (Natural Gas Production).

	Natural Gas Production	Energy Construction Repair and Maintenance Services	Corporate	HPG Inc. Consolidated
Gas production revenue	$ 2,143,458	$ -	$ -	$ 2,143,458
Service revenue	-	10,887,920	-	10,887,920
Other revenue	-	1,150,589	-	1,150,589
Total revenue	$ 2,143,458	$ 12,038,509	$ -	$ 14,181,967
Depreciation, Depletion, and Amortization	$ 1,854,199	$ 117,148	$ -	$ 1,971,347
Operating (loss)	$ (22,863,070)	$ (1,467,534)	$ (1,573,027)	$ (25,903,631)
Interest expense	(574,543)	(73,747)	-	(648,290)
Total assets	$ 3,126,384	$ 7,135,475	$ -	$ 10,261,859

Concentration. For the Natural Gas Properties segment, all of the Company’s revenue recorded from the sale of natural gas is generated through sales to two purchasers. For the Construction Services Segment, the Company’s top three customers account for 58% of total segment revenue.

The following table provides the percentage of revenue derived from natural gas sales to the Company’s top two customers for the six months ended June 30, 2012:

Customer A	82%
Customer B	18%

The following table provides the percentage of revenue derived from construction services sales to the Company's top three customers for the six months ended June 30, 2012:

Customer A	22%
Customer B	19%
Customer C	17%

NOTE 15: INCOME TAXES

Income Taxes. The Company has analyzed filing positions in all of the federal and state jurisdictions where it is required to file income tax returns, as well as all open tax years in these jurisdictions. No uncertain tax positions have been identified as of June 30, 2012.

The Company is generally no longer subject to U.S. federal income tax examinations by the Internal Revenue Service for tax years before 2008, and for state and local tax authorities for years before 2007.

The Company is in a position of cumulative reporting losses for the current and preceding reporting periods. The volatility of energy prices and uncertainty of when energy prices may rebound is not readily determinable by management. At this date, this fact pattern does not allow the Company to project sufficient sources of future taxable income to offset tax loss carry forwards and net deferred tax assets. Under these circumstances, it is management’s opinion that the realization of these tax attributes does not reach the “more likely than not criteria” under Financial Accounting Standards Board (FASB) Accounting Standards Codification (ASC) 740 – Income Taxes. As a result, the Company’s deferred tax assets as of September 30, 2012 and December 31, 2011 are subject to a full valuation allowance.

2825

reach the “more likely than not criteria” under Financial Accounting Standards Board (FASB) Accounting Standards Codification (ASC) 740 – Income Taxes. As a result, the Company’s deferred tax assets as of June 30, 2012 and December 31, 2011 are subject to a full valuation allowance.

NOTE 16: FAIR VALUE MEASUREMENT AND DISCLOSURE

The Company has adopted ASC 820, Fair Market Measurement and Disclosures including the application of the statement to non-recurring, non-financial assets and liabilities. The adoption of ASC 820 did not have a material impact on the Company’s fair value measurements. ASC 820 defines fair value as the price that would be received to sell an asset or paid to transfer a liability in the principal or most advantageous market for the asset or liability in an orderly transaction between market participants at the measurement date. ASC 820 establishes a fair value hierarchy, which prioritizes the inputs used in measuring fair value into three broad levels as follows:

Level 1-

Quoted prices in active markets for identical assets or liabilities.

Level 2-

Inputs, other than the quoted prices in active markets that are observable either directly or indirectly.

Level 3-

Unobservable inputs based on the Company’s own assumptions,

Fair Value Measurements at June 30, 2012 using:

Description	Quoted Prices in Active Markets for Identical Assets (Level 1)	Significant Other Observable Inputs (Level 2)	Significant Unobservable Inputs (Level 3)
Commodity hedge	$ -	$ 1,094,602	$ -
Natural gas properties	$ -	$ -	$ -
Intangible assets, net	$ -	$ -	$ 3,087,066

Level 3 assets are comprised of gas properties and related equipment and intangible assets consisting of customer relationships and employment agreements. The Company classifies these assets as a Level 3 due to the lack of available data to obtain market values for the unevaluated properties. The company considered current natural gas prices and the remaining lease term as a basis for determining the fair value.

Level 3 Reconciliation Table	Natural Gas Properties
Balance at December 31, 2011		$ 13,742,933
Additions at cost		561,051
Depletion, depreciation, and
amortization		(863,115)
Impairment to fair value		(13,440,869)
Balance at June 30, 2012		$ -

		Intangible Assets
Balance at December 31, 2011		$ 7,496,360
Impairment to fair value		(3,604,645)
Accumulated amortization		(804,649)
Balance at June 30, 2012		$ 3,087,066

Financial Instruments

Financial instruments not measured at fair value on a recurring basis include cash and cash equivalents, accounts receivable, and accounts payable, accrued liabilities, lines of credit and long-term debt. With the exception of the long-term debt, the financial statement carrying amounts of these items approximate their fair values due to their short-term nature. The carrying amount of long-term debt approximates the fair value due to its floating rate structure.

NOTE 17: HEDGING AND DERIVATIVE FINANCIAL INSTRUMENTS

The Company ~~utilizes~~utilized a swap contract to hedge the effect of price changes on a portion of its ~~future~~ natural gas production. The objective of the Company's hedging activities and the use of a derivative financial instrument iswas to achieve more predictable cash flows. While the use of a derivative instrument limits the downside risk of adverse price movements, they also may limit future revenues from favorable price movements.

The use of a derivative involves the risk that the counterparties to such instruments will be unable to meet the financial terms of such contracts. . The derivative contract may be terminated by a non-defaulting party in the event of default by one of the parties to the agreement. The Company is not required to post collateral when the Company is in a derivative liability position.

AsDuring ofthe ~~June~~nine months ended September 30, 2012 and 2011, the Company had ~~entered into a~~ swap ~~agreement~~agreements related to its natural gas production. Location and quality differentials attributable to the Company's properties ~~are~~were not included. The agreement provides for monthly settlement based on the differential between the agreement price and the actual CIG Rocky Mountains price.

~~During~~On ~~the~~or ~~six~~about ~~months~~August ~~ended June 30~~15, 2012, the Company ~~recognized~~entered ~~$1,806,696~~into ofa ~~realized~~transaction, ~~net~~termination ~~gains~~ and ~~($1,087,799)~~liquidation inagreement ~~unrealized~~whereby ~~losses~~its ~~related to our~~ hedging arrangement~~. During~~ ~~the~~was ~~six~~terminated. ~~months~~Proceeds ~~ended~~of ~~June 30~~$767,170 ~~2011,~~were wecredited ~~recognized~~by ~~$208,505~~Amegy inagainst ~~realized~~the ~~gains~~outstanding asbalance ~~well~~of asour ~~($28,215)~~line of ~~unrealized~~credit ~~losses~~ related to ~~our~~cash ~~hedging~~payments ~~arrangement~~from the Hedge (Note 14).

OnDuring orthe ~~about~~three ~~August~~months 15ended September 30, 2012 the Company ~~entered~~recognized ~~into~~net agains ~~transaction, termination and liquidation agreement whereby its hedging arrangement (Note 20) was terminated. In connection therewith we recorded a realized loss~~ on ~~the~~ settlement of ($~~113~~52,~~248)~~837 asrelated ofto ~~June~~hedge 30settlements, ~~2012~~no ~~and~~unrealized ~~adjusted~~gains ~~the~~or ~~market~~losses ~~value~~were ofrecognized. During the ~~hedge~~nine tomonths ~~reflect~~ended ~~the~~September ~~terminal~~30, ~~value~~2012 ofthe ~~all~~Company ~~payments~~recognized tonet begains ~~received subsequent to June 30, 2012. This amount~~ of $1771,~~094,602~~733 ~~has~~in ~~been~~connection ~~recorded~~with ashedge ~~a current asset on our unaudited condensed consolidated balance sheet as of June 30, 2012~~settlement.

NOTE 18: COMMITMENTS AND CONTINGENCIES

~~Operating~~Financing ~~leases~~Arrangement. On February 29, 2012, the Company entered into an exclusive agreement for financial advisory services; wherein, the Company will pay to the advisor cash payments and / or warrants for any financing or M&A transactions culminated within one year from the effective date of the agreement. The cash and / or warrant based compensation would be based on the value of the culminated transactions. This agreement has lapsed.

Employment Contracts. The Company is ~~currently~~party ~~renting~~to ~~office~~several ~~and~~employment ~~manufacturing~~agreements ~~space~~with atkey personnel, all of which began on various ~~locations~~effective ~~under~~dates ~~non-cancelable~~ranging ~~operating~~from ~~leases~~January ~~extending~~1, 2011 through ~~2016~~March 1, 2012. ~~Future~~The ~~minimum~~agreements ~~operating~~provide ~~lease~~annual ~~payments~~salaried ~~with~~compensation ~~initial~~ranging ~~terms~~from of$70,000 ~~one~~to ~~year~~$175,000 orand ~~more~~all ~~are~~contain similar terminology as ~~follows:~~to termination criteria.

3026

Year ended December 31,		Amount
2012		$ 345,000
2013		810,000
2014		1,083,081
2015		1,049,465
2016		785,663
Thereafter		-
Total Minimum Lease Payments		$ 4,073,209

Delivery Commitments. A portion of our production is sold under certain contractual arrangements that specify the delivery of a fixed and determinable quantity. The following table sets forth information about material long-term firm transportation contracts for pipeline capacity. Although exact amounts vary, as of September 30, 2012, we were committed to the following financial commitments related our natural gas production:

Rent expense during the six months ended June 30, 2012 and 2011 was $704,892 and $105,500, respectively.

Financing Arrangement

On February 29, 2012, the Company entered into an exclusive agreement for financial advisory services; wherein, the Company will pay to the advisor cash payments and / or warrants for any financing or M&A transactions culminated within one year from the effective date of the agreement. The cash and / or warrant based compensation would be based on the value of the culminated transaction(s).

Employment Contracts

The Company is party to several employment agreements with key personnel, all of which began on various effective dates ranging from January 1, 2011 through March 1, 2012. The agreements provide annual salaried compensation ranging from $70,000 to $175,000 and all contain similar terminology as to termination criteria.

Delivery Commitments

A portion of our production is sold under certain contractual arrangements that specify the delivery of a fixed and determinable quantity. The following table sets forth information about material long-term firm transportation contracts for pipeline capacity. Although exact amounts vary, as of June 30, 2012, we were committed to the following financial commitments related our natural gas production:


Type of Arrangement	Pipeline System / Location	Deliverable Market		Expiration
Type of Arrangement	Pipeline System / Location	Deliverable Market	Commitment ($/month)	Expiration
Firm Transport	WC	CIG – Rocky Mountains	$65,433	November 2015

As High Plains Gas, Inc. shut in its gas producing assets in May 2012, ~~the~~and ~~Company~~ is ~~assessing~~in ~~the~~default ~~impact~~ of ~~the curtailment related to~~ its delivery commitment.

Litigation. In July 2012, the Company received notice from local tax authorities that it had been named in two civil suits related to unpaid personal and property taxes related to fiscal years 2007, 2008, 2009, 2010 and 2011. The damages cited in the suits amounted to $274,828. This amount has been accrued in our consolidated balance sheet as of September 30, 2012.

On May 7, 2013 an action was filed in the District Court of Campbell County, Wyoming titled Pennaco Energy, Inc. v. Cep-M Purchase, LLC, Current Energy Partners Corporation, High Plains Gas, Inc., High Plains Gas, LLC, Mark Hettinger, Jerri Hettinger, Brandon Hargett, Joseph Hettinger and Brent Cook (the “Pennaco Action”). In the Pennaco Action, Pennaco alleges that at the time Current Energy Partners acquired the North and South Fairway Assets through CEP-M Purchase in July ~~2012~~2010, that CEP-M Purchase had failed to comply with the ~~Company~~terms ~~received~~of ~~notice~~the ~~from~~purchase ~~local~~agreement, ~~tax~~including ~~authorities~~without limitation payment of approximately $3,354,931 towards the original $10,570,000 purchase price. Pennaco further alleges that itCEP-M Purchase had ~~been~~provided ~~named~~numerous false and/or misleading representations in ~~two~~the ~~civil~~purchase ~~suits~~agreement. Pennaco ~~related~~alleges tothat ~~unpaid~~Current ~~personal~~Energy Partners guaranteed the obligations of CEP-M Purchase. Pennaco further alleges that the defaults of CEP-M Purchase and ~~property~~Current ~~taxes~~Energy ~~related~~Partners tohas ~~fiscal~~resulted ~~years~~in ~~2007~~numerous further legal actions against Pennaco and others causing further damages. Pennaco further alleges that the Company as well as its operating subsidiary High Plains Gas LLC, ~~2008~~and certain former officers and directors of the Company, ~~2009~~are liable for the damages as “alter egos” of CEP-M Purchase and/or Current Energy Partners. Pennaco also alleges that the named principals undermined the potential for success of the acquisition by failing to adequately finance operations, ~~2010~~failing to provide appropriate and ~~2011~~required bonding, and by failing to assume certain contracts. Pennaco’s ~~The~~action ~~damages~~includes ~~cited~~breach of contract in the ~~suits~~purchase ~~amounted~~agreement, breach of a guaranty agreement, breach of the implied covenant of good faith and fair dealing, unjust enrichment, conversion, fraud, negligent misrepresentation, injunctive relief, and seeks to ~~$274~~pierce the corporate veil with respect to the Company,~~828.~~ its operating subsidiary and with respect to the individual defendants.

31The Company has been in discussions with Pennaco towards resolution of this action and is confident that a resolution can be reached. Absent such a resolution, the Company has vigorously defended this action and believes that the allegations with respect to the Company and its operating subsidiary are unfounded. The Company intends to continue to seek to reach resolution and/or vigorously defend the action.

~~Environmental Impact~~27

Environmental Impact. The Company is engaged in gas exploration and production and may become subject to certain liabilities as they relate to environmental cleanup of well sites or other environmental restoration procedures as they relate to the drilling of oil and gas wells and the operation thereof. If the Company acquires existing or previously drilled well bores, the Company may not be aware of what environmental safeguards were taken at the time such wells were drilled or during such time the wells were operated. Should it be determined that a liability exists with respect to any environmental cleanup or restoration, the liability to cure such a violation could fall upon the Company. Management believes its properties are operated in conformity with local, state and federal regulations. No claim has been made, nor is the Company aware of any uninsured liability which the Company may have, as it relates to any environmental cleanup, restoration or the violation of any rules or regulations relating thereto.

NOTE 19: OTHER MATTERS

Funds in Escrow. During 2010, the Company incurred a $750,000 bond commitment fee with PP&J, a Wyoming entity. This fee was to be satisfied by issuance of 800,000 common shares to PP&J. As the shares were restricted and could not be readily disposed to satisfy the obligation, a deposit of $750,000 was made to an escrow account held at First National Bank of Gillette, Wyoming. If the value of the shares held by PP&J was less than the $750,000 as of the date that the shares became unrestricted any shortfall would have been satisfied utilizing the funds in escrow. During the three months ended June 30, 2012 an agreement was reached whereby the commitment was deemed to have been satisfied. Funds were released from escrow and the common shares were returned to the Company’s treasury. In connection thereto the Company has recognized a loss on the extinguishment of the liability in the amount of $63,746.

Bond Commitment Fees. Fees paid to secure commitments from lenders and to secure bonding arrangements with the state and other local government entities are capitalized and amortized on a straight-line basis over the expected term of the arrangement. Amortization of these fees during the ~~six~~nine months ended ~~June~~September 30, 2012 and 2011 totaled $nil and $~~585~~1,~~227~~975,994, respectively.

NOTE 20: SUBSEQUENT EVENTS

Pursuant to FASB ASC 855 “Subsequent Events”, management has evaluated all events and transactions that occurred from ~~June~~September 30, 2012 through the date of issuance of the financial statements. During this period we did not have any significant subsequent events, except as disclosed below:

In July 2012, the Company received notice from local tax authorities that it had been named in two civil suits related to unpaid personal and property taxes related to fiscal years 2007, 2008, 2009, 2010 and 2011. The damages cited in the suits amounted to $274,828. ·

On orSeptember ~~about August 15~~18, 2012 ~~the Company entered into a transaction~~, ~~termination~~Eide ~~and~~Bailly ~~liquidation~~LLP ~~agreement~~resigned ~~whereby~~as ~~its hedging arrangement (Note 17) was terminated. In connection therewith~~ the ~~Company~~independent ~~recorded~~registered apublic ~~realized~~accounting ~~loss~~firm ~~on the settlement~~ of ~~($113,248) as of June 30, 2012 and adjusted~~ the ~~value of the hedge to reflect the value of all payments to be received subsequent to June 30, 2012~~Company.~~This amount of $1,094,602 has been recorded as a current asset on our unaudited consolidated balance sheet as of June 30, 2012.~~

On or about August 15, 2012 an agreement was reached with Amegy Bank whereby $813,277 of the remaining hedge payments as referenced above were assigned to Amegy to be utilized as payments against the outstanding principal balance due under our line of credit with the bank (Note 11).·

32Effective October 3, 2012, Ty Miller resigned as a director of the Company. The Board of Directors of the Company accepted Mr. Miller’s resignation.

On October 4, 2012, the Company engaged Stark Schenkein, LLP (“Stark”) as its independent registered public accounting firm for the Company’s fiscal year ending December 31, 2012. The decision to engage Stark as the Company’s independent registered public accounting firm was approved by the Company’s Board of Directors.

On October 8, 2012, the Company executed a Letter of Intent with Broadmark Energy, LLC (“Broadmark”) for the acquisition of certain assets and the assumption of certain liabilities related to the energy construction /oil and gas services business, including equipment and accounts

receivable, of Miller Fabrication LLC, HPG Services, LLC, High Plains Gas, Inc. and High Plains Gas, LLC. The terms of the proposed transaction, under the Letter of Intent, are substantially as follows:

Broadmark will acquire all of the assets and assume certain liabilities of Miller Fabrication in consideration for (i) assumption of up to the current level ($3,000,000) of accounts payable and accrued liabilities of Miller; (ii) assumption of certain Miller Fabrication notes payable in the amount of $3,100,000; (iii) assumption of an obligation of the Company to Tonaquint, Inc. (approximately $1,775,538) and (iv) cash consideration of $200,000.

The principals of Miller will cancel and return a total of 54,000,000 shares of common stock of the Company, as well as any and all options or warrants to purchase shares of stock of the Company as part of the transaction.

Broadmark will assume the investment banking fees owed to Broadmark Capital, LLC by the Company, but the Company will remain responsible for issuing financing warrants in the Company per a previous agreement.

On October 9, 2012, the Company executed a Letter of Intent with Chama Technologaes, Inc. (“Chama”) a Nevada corporation, for the purchase by Chama of a controlling stock interest in the Company. The terms of the proposed acquisition, under the Letter of Intent, are substantially as follows:

In consideration for a total of $15,000,000 in cash and 658,289 shares of Chama stock, the Company will issue a fully diluted 90% of its common stock to Chama at Closing.

The letter of intent requires that Chama place into an escrow account for payment to the creditors of the Company prior to the acquisition a total of $10,000,000, deliverable in increments. The increments are that in 10 working days from execution of the letter of intent, Chama is to deposit $1,000,000 and in 20 working days after the initial increment, Chama is to deposit an additional $9,000,000. Chama will then continue to fund the remaining $5,000,000 into escrow to finish creditor payments.

The Letter of Intent includes other terms including funding the termination of an outstanding class of preferred stock and buyout at a discount of any and all outstanding options and warrants.

The Letter of Intent also requires the divestiture of Miller Fabrication, LLC, the oil and gas servicing subsidiary of the Company.

Effective October 17, 2012, Mark Hettinger resigned as an Officer and Director of the Company. The Board of Directors of the Company accepted Mr. Hettinger’s resignation.

On October 29, 2012, the Company executed an amendment to its Letter of Intent with Chama for the purchase by Chama of a controlling stock interest in the Company. The amendment extends the Escrow Date for required payments into escrow; the initial $1,000,000 shall be paid into escrow on or before November 5, 2012, and the final $9,000,000 shall be paid into escrow on or before November 15, 2012.

On February 20, 2013 the Company completed a purchase and sale agreement whereby Miller Fabrication, LLC was sold. Broadmark acquired all of the identifiable assets and assumed certain liabilities of Miller Fabrication in consideration for the assumption of accounts payable and accrued liabilities of Miller; assumption of certain Miller Fabrication notes payable assumption of an obligation of the Company to Tonaquint, Inc. (approximately $1,775,538) and cash consideration of $200,000.

On March 28, 2013, the Company executed an Agreement and Plan of Merger between the Company and Chama for the purchase by Chama of a controlling stock interest in the Company. The terms of the acquisition are substantially as follows:

The Agreement requires that the Company complete a 1 for 1,000 reverse split of its common stock. The Company has not be able to complete the reverse split because the rules of FINRA require that the Company be current in its financial reporting obligations.

Upon completion of the reverse stock split, the Company will have approximately 305,000 shares of common stock outstanding. Pursuant to the merger, the Company will issue to Chama shareholders 25,000,000 shares of the Company’s common stock. Upon execution of the Agreement and completion of the merger set forth therein, the shareholders of Chama shall have majority control of the Company.

The Company assumes approximately $4,000,000 in obligations owed by Chama.

Effective March 28, 2013, Siva Mohan, Alan Smith and Cordell Fonnesbeck resigned as directors of the Company.

On March 28, 2013, a majority of the shareholders of the Company appointed Ed Presley, William Helfer and William Edwards as directors of the Company.

On March 28, 2013, the Board of Directors appointed Ed Presley as President and Chief Executive Officer.

Effective March 29, 2013, Joseph Hettinger resigned as a director of the Company.

On March 29, 2013, Stark resigned as the independent registered public accounting firm of the Company. Stark had not performed any material audit work for the Company

On April 26, 2013, the Company engaged the firm of D’Arelli Pruzansky, P.A., Certified Public Accountants, to serve as its independent registered public accountants for the fiscal year ending December 31, 2012. The decision to engage new accountants was recommended and approved by the Company’s Board of Directors.

In May 2013, Pennaco Energy, Inc. brought legal action against the Company, CEP-M Purchase, LLC, Current Energy Partners Corporation, High Plains Gas LLC and certain former officers and directors of the Company. See “Legal Proceedings.”

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

The following discussion and analysis should be read in conjunction with the accompanying unaudited condensed consolidated financial statements and related notes included elsewhere in this report. It contains forward-looking statements that reflect our future plans, estimates, beliefs and expected performance. The forward-looking statements are dependent upon events, risks and uncertainties that may be outside our control. Our actual results could differ materially from those discussed in these forward looking statements. Factors that could cause or contribute to such differences include, but are not limited to, the following risks and uncertainties:

Amounts and nature of future revenues and margins from our Oil and Gas and Construction Services segments;

the likely impact of new or existing regulations or market forces on the demand for our services;

expansion and other development trends of the industries we serve;

our ability to generate sufficient cash from operations or to raise cash in order to meet our short and long-term capital requirements;

our ability to comply with the covenants in our Credit Facilities and Debt Instruments;

the potential for production decline rates from our wells to be greater than we expect;

changes in estimates of proved reserves;

occurrence of property acquisitions or divestitures;

reduced creditworthiness of our customer base and higher risk of non-payment of receivables;

inability to obtain sufficient surety bonds or letters of credit;

project cost overruns, unforeseen schedule delays and the application of liquidated damages;

cancellation of projects, in whole or in part, for any reason;

ability to access capital markets to adequately fund the needs of the Company

Business Overview

High Plains Gas, Inc., (the “~~High~~Company”, ~~Plains~~“We, ~~Gas~~“Our”), is a ~~provider~~Nevada ofcorporation, ~~goods~~together ~~and~~with its wholly owned subsidiaries, provides construction services, toand ~~regional~~repair ~~end~~and ~~markets~~maintenance ~~serving~~services primarily to the energy ~~industry. We~~and ~~produce~~energy related industries primarily located in Wyoming, North Dakota, Montana, Oklahoma and Texas, and produces natural gas in the Powder River Basin ~~located~~ in Northeast Wyoming. WeDuring ~~provide~~our ~~construction~~fiscal ~~services~~year ended December 31, ~~and~~2011, ~~repair~~we ~~and~~commenced ~~maintenance~~a ~~services~~strategic shift in operations from primarily natural gas production to ~~the~~a ~~energy~~more ~~and~~focused ~~energy~~approach ~~related~~towards ~~industries~~energy ~~mainly~~construction ~~located~~services inand ~~Wyoming~~repair and ~~North~~maintenance ~~Dakota~~services. ~~Our~~ ~~strategic~~During ~~shift~~the tothree amonths ~~more~~ended ~~balanced~~June ~~focus~~30, ~~between~~2012 ~~providing~~we ~~goods~~shut ~~and~~in ~~services~~our ~~has~~natural ~~realized~~gas aproducing ~~more~~assets. ~~diversified~~In ~~revenue~~February ~~stream~~2013, ~~for~~our ~~the~~construction ~~company. Although~~services wedivision ~~maintain~~discontinued ~~the~~its ~~strategy~~operations toprimarily ~~seek~~through ~~high~~the ~~quality~~disposition ~~development~~of ~~projects~~Miller inFabrication, ~~the~~LLC ~~oil~~(“Miller”) ~~and~~(Note ~~gas~~5). On ~~industry~~March 28, 2013, we ~~intend~~executed toan ~~continue~~Agreement ~~our~~and ~~very~~Plan ~~important~~of ~~strategic~~Merger ~~shift~~between tothe ~~expand~~Corporation ~~into~~and ~~the~~Chama ~~energy~~Technologaes, ~~construction~~Inc. ~~services~~(“Chama”), ~~and~~a ~~repairs~~Nevada ~~and~~corporation, ~~maintenance~~for ~~services~~the ~~through~~purchase ~~growth~~by Chama of ~~our~~a ~~existing~~controlling ~~operations~~stock interest in High Plains.

WeThe ~~have~~terms ~~two~~of ~~reportable segments,~~ the ~~energy~~acquisition ~~construction~~are ~~services~~substantially ~~division~~as ~~and the natural gas segment.~~ follows:

The Agreement requires that the Company complete a 1 for 1,000 reverse split of High Plains Gas common stock. . The Company has not be able to complete the reverse split because the rules of FINRA require that the Company be current in its financial reporting obligations. Upon completion of the reverse stock split, we will have approximately 305,000 shares of common stock outstanding. Pursuant to the merger, we were to issue to Chama shareholders 25,000,000 shares of High Plains Gas stock. We

assumed approximately $4,000,000 in obligations owed to previous shareholders of RWM Resources, Inc. an entity that was previously owed by Chama.

As the Company is delinquent in its filings with the U.S. Securities and Exchange Commission (“SEC”) the impact of the merger agreement has not been effectuated in the accompanying unaudited financial statements.

We historically had two reportable segments, the energy construction services division and the natural gas segment.

Energy Construction, Repair and Maintenance Services

The discontinued Energy Construction, Services and Repair and Maintenance Services segment iswas a leading provider of services to regional end markets serving the oil and gas, refinery, petrochemical and power industries. Our services, which ~~include~~included engineering, procurement and construction, turnaround, maintenance and other specialty services are critical to the ongoing expansion and operation of energy infrastructure~~. Within~~ ~~the~~were ~~regional~~discontinued ~~energy market, we specialize~~ in ~~designing,~~February ~~constructing, upgrading and repairing midstream infrastructure such as pipelines, compressor stations and related facilities for onshore locations as well as downstream~~ 2013.

facilities, such as refineries. We also provide specialty turnaround services, tank services, heater services, and construction services and fabricate specialty items for hydrocarbon processing units. Our services include maintenance and small capital projects for transmission and distribution facilities for electric and natural gas utilities.

Natural Gas Production

~~The~~In ~~primary~~May ~~operations~~2012, ofwe shut in our ~~Natural~~gas ~~Gas~~producing ~~Production~~assets. ~~attempts~~Our decision to ~~seek~~shut ~~profitability~~ in ~~existing~~production ~~natural~~was ~~gas~~the ~~production~~result ~~programs~~of ~~through~~volatile ~~existing~~prices ~~fields. Substantially~~for ~~all~~natural ofgas ~~this~~in ~~segment’s~~the ~~revenues~~Powder ~~are~~River ~~generated~~basin ~~through~~and the ~~sale~~disproportionate use of our working capital utilized in natural gas atproduction. ~~market~~We ~~prices~~have ~~and~~no ~~the~~immediate ~~settlement~~plans ofto ~~commodity~~resume ~~hedges~~production.

In May, 2012 we shut in our gas producing assets. Our decision to shut in production was the result of volatile prices for natural gas in the Powder River basin and the disproportionate use of our working capital utilized in natural gas production. We have no immediate plans to resume production.

Results of Operations

The financial information for the three and ~~six~~nine months ended ~~June~~September 30, 2012 and 2011 that is discussed below is unaudited. In the opinion of management, such information contains all material adjustments, consisting only of normal and recurring adjustments, necessary for a fair presentation of the results for such periods. The results of operations for interim periods are not necessarily indicative of the results of operations for the full fiscal year.

Three Months Ended ~~June~~September 30, 2012 Compared to Three Months Ended ~~June~~September 30, 2011

During the three months ended ~~June~~September 30, 2012, oil and gas revenues decreased to $~~619,542,~~nil from $32,~~379~~784,~~997~~663 for the corresponding prior period. The effects of realized hedges only include settlements from hedging instruments that were designated as cash flow hedges. Production volumes decreased to ~~564,413~~nil Mcf for the three months ended ~~June~~September 30, 2012 from 1,~~008~~129 Mcf for the corresponding prior period. Decreases ~~relate~~are due to ~~normal~~shutting ~~decline curves~~ in our ~~wells,~~natural ~~decreased~~gas ~~spending on workovers and maintenance on our~~ producing ~~wells,~~assets ~~significant decreases in prices for natural gas~~ during the period ~~and~~ended ~~our~~June ~~curtailment of production in May~~30, 2012.

During the three months ended ~~June~~September 30, 2012, ~~service~~we ~~revenue~~incurred ~~totaled~~lease operating expense and production taxes of $5228,~~628,374~~999 ~~with~~as nocompared ~~comparable~~to ~~activity~~$1,514,961 in the prior period. Decreases ~~given~~in ~~the~~lease ~~Company’s~~operating ~~entry~~expenses ~~into~~and ~~the~~related ~~services~~taxes ~~business~~are indue ~~October~~to ~~2011~~shutting ~~with~~in ~~the~~our ~~acquisition~~natural ofgas ~~Miller~~producing ~~Fabrication,~~assets ~~LLC~~during ~~and~~the ~~increased~~period ~~operations~~ended ~~from~~June ~~our~~30, ~~pre-existing services segment~~2012.

During the three months ended ~~June~~September 30, 2012, wegeneral ~~incurred~~and ~~lease~~administrative ~~operating~~ expense ~~and~~decreased ~~production~~to ~~taxes of~~ $21,~~496~~462,~~361~~578 as compared to $31,~~166~~759,~~764~~713 in the corresponding prior period. ~~Increases~~ General inand ~~lease~~administrative ~~operating~~expense ~~expenses~~for ~~and~~the ~~related~~three ~~taxes~~months ~~resulted~~ended ~~from~~September ~~charges~~30, ~~related~~2012 towas ~~accelerated~~composed ~~accrued~~primarily ~~capital~~of ~~expenditures~~salaries ~~offset~~and bywages ~~decreases~~of in$362,966, ~~production~~consulting ~~volumes~~fees ~~offset~~of by$974, ~~curtailment~~and legal and accounting fees of ~~production~~$206,137. Non-cash stock-based compensation totaling $670,254 has been included in ~~May~~general and administrative expense for the three months ended September 30, 2012 compared to $204,000 in the corresponding prior period.

During the three months ended June 30, 2012, cost of services totaled $5,389,931 with no comparable activity in the prior year given the Company’s entry into the services business in October 2011 with the acquisition of Miller Fabrication, LLC and increased operations from our pre-existing services segment.32

During the three months ended ~~June~~September 30, 2012, ~~general~~Depreciation, Depletion and ~~administrative~~Amortization (“DD&A”) expense ~~decreased~~totaled to $2247,~~444,931compared~~504 as compared to $41,~~021~~844,~~289~~446 induring the corresponding prior period. ~~General~~ Accretion ~~and administrative~~ expense ~~for~~related to the ~~three~~Company’s ~~months~~Asset ~~ended~~Retirement ~~June~~Obligation ~~30, 2012~~ was ~~composed primarily of salaries and wages of~~ $~~445~~nil,~~859,~~ ~~consulting~~as ~~fees~~compared ofto $~~328,635,~~nil ~~and~~during ~~legal~~the ~~and~~corresponding ~~accounting~~prior ~~fees of $426,741~~period. ~~Non-cash stock-based~~

During the three months ended September 30, 2012, our realized commodity derivative gain totaled $52,837 compared to a realized $129,140 gain during the corresponding prior period. We recognized no unrealized commodity derivative losses during the quarter ended September 30, 2012 as of hedge arrangement was terminated during the fiscal quarter, as compared to unrealized commodity derivative gains of $1,157,117 for the corresponding prior period.

During the three months ended September 30, 2012, the Company’s impairment, dry hole costs and abandonment expense totaled $nil compared to $2,565,270 for the corresponding prior period. Impairment charges recorded during the quarter ended September 30, 2012 relate to the shutting in of production in June, 2012. Impairment charges recorded in the comparable prior period related to the Company’s unevaluated leasehold costs, shut in drilling equipment, and evaluated shut in equipment.

During the three months ended September 30, 2012, the Company’s impairment expense relating to other assets totaled $240,757 compared to $nil for the corresponding prior period. Impairment charges recorded during the quarter ended September 30, 2012 relate to SCADA systems and related computer equipment used solely in the oil and gas field operations, written off due to the shutting in of wells in June 2012.

During the three months ended September 30, 2012, the Company recorded losses on extinguishment of debt of $360,015 compared to $4,323,581 during the corresponding prior period. Loss on extinguishment of debt during the three months ended September 30, 2012 consisted of losses of approximately $201,000 and $125,000 in extinguishment of liabilities to state and local municipalities. The Company has posted certificates of deposit which were seized in satisfaction of failure to remit severance and ad-valorem taxes. Additional charges of approximately $33,000 were incurred in connection with the conversion of debt instruments. Charges incurred in the prior period relate primarily to the conversion of related party debt $3,850,000 coupled with the settlement of debt with Ironridge $425,000.

During the three months ended September 30, 2012, interest expense increased to $1,941,601 from $549,843 during the corresponding prior period and amortization of loan fees decreased to $109,848 from $807,743 during the corresponding prior period. Increases in interest expense during the current period relate primarily to interest and liquidating damages recorded in connection with our default on the Tonaquint note and the increase in notes payable balance due Miller in the amount of $3,000,000 as of September 30, 2012 which was not outstanding during the comparable prior period.

During the three months ended September 30, 2012, net (loss) from continuing operations decreased by $6,554,920 from ($11,032,337) in 2011 to ($4,477,417) in 2012. Losses from discontinued operations amounted to $5,353,241 for the three months ended September 30, 2012 as compared to $nil in the comparable prior period.

Nine Months Ended September 30, 2012 Compared to Nine Months Ended September 30, 2011

During the nine months ended September 30, 2012, oil and gas revenues decreased to $2,143,458, from $10,191,744 for the prior period. The effects of realized hedges only include settlements from hedging instruments that were designated as cash flow hedges. Production volumes decreased to 1,497,775 Mcf for the nine months ended September 30, 2012 from 3,409,000 Mcf for the corresponding prior period. Decreases are due to shutting in our natural gas producing assets during the period ended June 30, 2012.

During the nine months ended September 30, 2012, we incurred lease operating expense and production taxes of $4,790,737 as compared to $10,443,214 in the prior period. Decreases in lease operating expenses and related taxes are due to shutting in our natural gas producing assets during the period ended June 30, 2012.

During the nine months ended September 30, 2012, general and administrative expense increased to $6,693,859 compared to $6,401,347 in the corresponding prior period. General and administrative expense for the nine months ended September 30, 2012 was composed primarily of salaries, wages and benefits of $1,281,313, consulting, legal and accounting expenses of $1,450,138, and insurance of $233,853. In addition, non-cash stock-based compensation totaled $2,691,932 was included in general and administrative expense for the nine months ended September 30, 2012 as compared to $1,017,004 in the corresponding prior period.

During the nine months ended September 30, 2012, Depreciation, Depletion, Amortization and Accretion expense totaled $2,461,445 as compared to $5,580,557 during the prior period. Accretion expense related to the Company’s Asset Retirement Obligation was $359,741, as compared to $568,820 during the prior period. Decreases in accretion related to the Asset Retirement Obligation relate to revisions to estimates recorded during fiscal year ended December 31, 2011 coupled with a shutting in of production in May, 2012.

During the nine months ended September 30, 2012, our realized commodity derivative gain totaled $771,733 compared to $337,645 during the prior period. Our unrealized commodity derivative loss totaled $nil compared to a gain of $1,128,902 for the prior period. Increases in recognized gains relate to market prices for natural gas and decreases in unrealized gains relate to the fact that our hedge was terminated during the quarter ended September 30, 2012.

During the nine months ended September 30, 2012, the Company’s impairment, dry hole costs and abandonment expense totaled $13,440,869 compared to $2,565,270 for the prior period. Impairment charges recorded during the current period relate primarily to the shutting in of production in May 2013. Impairment charges recorded in the comparable prior period related to the Company’s unevaluated leasehold costs, shut in drilling equipment, and evaluated shut in equipment.

During the nine months ended September 30, 2012, the Company’s impairment expense relating to other assets totaled $240,757 compared to $nil for the corresponding prior period. Impairment charges recorded during the nine months ended September 30, 2012 relate to SCADA systems and related computer equipment used solely in the oil and gas field operations, written off due to the shutting in of wells in June 2012.

During the nine months ended September 30, 2012, the Company recorded losses on extinguishment of debt of $1,649,314 compared to $4,856,513 during the prior period.

During the nine months ended September 30, 2012, interest expense increased to $2,516,143 from $1,855,288 during the prior period. Increases during the current period relate primarily to the addition of $6,000,000 in related party notes payable during the current period and charges for liquidating damages and penalties incurred in connection with our Tonaquint note, amortization of loan fees decreased to $341,801 from $2,403,173 during the prior period.

During the nine months ended September 30, 2012, our net (loss) from continuing operations increased by $168,834 from ($29,815,661) in 2011 to ($29,984,495) in 2012, while our loss from discontinued operations increased to $9,019,698 from $0 related to the discontinued operations of our Energy Construction Services and Repair and Maintenance Services division.

compensation totaling $670,254has been included in general and administrative expense for the three months ended June 30, 2012 compared to $220,553 in the corresponding prior period.

During the three months ended June 30, 2012, Depreciation, Depletion and Amortization (“DD&A”) expense totaled $1,021,173 as compared to $1,364,096 during the corresponding prior period. Accretion expense related to the Company’s Asset Retirement Obligation was $172,468, as compared to $219,224 during the corresponding prior period.

During the three months ended June 30, 2012, our realized commodity derivative gain totaled $1,072,170 compared to a realized $56,760 gain during the corresponding prior period. Our unrealized commodity derivative loss totaled $1,460,312 compared to a gain of $392,699for the corresponding prior period.

During the three months ended June 30, 2012, the Company’s impairment, dry hole costs and abandonment expense totaled $12,953,082 compared to $4,125,010 for the corresponding prior period.

During the three months ended June 30, 2012, the Company recorded impairment expense on intangibles related to the Miller Fabrication LLC acquisition of $3,604,645, compared to $nil for the corresponding prior period.

During the three months ended June 30, 2012, the Company recorded losses on extinguishment of debt of $37,181 compared to $532,932 during the corresponding prior period.

During the three months ended June 30, 2012, interest expense increased to $450,418 from $392,251 during the corresponding prior period and amortization of loan fees decreased to $158,146 from $742,262 during the corresponding prior period.

During the three months ended June 30, 2012, net (loss) increased by $11,508,646 from ($11,804,701) in 2011 to ($23,313,347) in 2012.

Six Months Ended June 30, 2012 Compared to Six Months Ended June 30, 2011

During the six months ended June 30, 2012, oil and gas revenues decreased to $2,143,458, from $7,407,781 for the prior period. The effects of realized hedges only include settlements from hedging instruments that were designated as cash flow hedges. Production volumes decreased to 1,497,775 Mcf for the six months ended June 30, 2012 from 2,134,000 Mcf for the corresponding prior period. Decreases relate to normal decline curves in our wells, decreased spending on workovers and maintenance on our producing wells, significant decreases in prices for natural gas during the period coupled with our curtailment of production in May, 2012.

During the six months ended June 30, 2012, service revenue totaled $12,038,509 with no comparable activity in the prior period given the Company’s entry into the services business in October 2011 with the acquisition of Miller Fabrication, LLC and increased operations from our pre-existing services segment.

During the six months ended June 30, 2012, we incurred lease operating expense and production taxes of $4,561,739 as compared to $7,292,902 in the prior period. Decreases in lease operating expenses and related taxes resulted from decreases in production volumes as discussed above coupled with the shutting in of our producing assets in May, 2012.

During the six months ended June 30, 2012, cost of services totaled $11,536,833 with no comparable activity in the prior year given the Company’s entry into the services business in October 2011 with the acquisition of Miller Fabrication, LLC and increased operations from our pre-existing services segment.

During the six months ended June 30, 2012, general and administrative expense increased to $5,603,875 compared to $6,276,985 in the corresponding prior period. General and administrative expense for the six months ended June 30, 2012 was composed primarily of salaries, wages and benefits of $872,943, consulting, legal and accounting expenses of $1,554,248, insurance of $279,368, and charges to allowance for doubtful accounts of $262,964. In addition, non-cash stock-based compensation totaled $2,021,778 was included in general and administrative expense for the six months ended June 30, 2012 as compared to $253,054 in the corresponding prior period.

During the six months ended June 30, 2012, Depreciation, Depletion and Amortization (“DD&A”) expense totaled $1,971,347 as compared to $3,347,365 during the prior period. Accretion expense related to the Company’s Asset Retirement Obligation was $359,741, as compared to $388,746 during the prior period.

During the six months ended June 30, 2012, our realized commodity derivative gain totaled $1,806,696 compared to $208,505 during the prior period. Our unrealized commodity derivative loss totaled ($1,087,799) compared to a loss of ($28,215) for the prior period.

During the six months ended June 30, 2012, the Company’s impairment, dry hole costs and abandonment expense totaled $13,440,869compared to $4,125,010for the prior period.

During the six months ended June 30, 2012, the Company recorded impairment expense on intangibles related to the Miller Fabrication LLC acquisition of $3,604,645, compared to $nil for the prior period.

During the six months ended June 30, 2012, the Company recorded losses on extinguishment of debt of $1,289,299 compared to $532,932during the prior period.

During the six months ended June 30, 2012, interest expense decreased to $648,290 from $1,305,445 during the prior period and amortization of fees decreased to $231,954 from $1,595,430 during the prior period.

During the six months ended June 30, 2012, net (loss) increased by $10,390,211from ($18,783,324) in 2011 to ($29,173,535) in 2012.

Liquidity and Capital Resources

At ~~June~~September 30, 2012, we had a working capital deficit of $2429,~~434~~709,~~463~~328 compared to $209,~~156~~488,~~107~~353 at December 31, 2011. The increase in our working capital deficit relates to cash used in operations coupled with increases in accounts payable and accrued liabilities resulting primarily from the shutting in of our natural gas production in May, 2012 coupled with decreases in our construction services revenue and the eventually discontinued operations of our Energy Construction Services and Repair and Maintenance Services division.

Our cash balance at ~~June~~September 30, 2012 was $~~383~~44,~~766~~681 as compared to $~~435~~321,~~015~~227 at December 31, 2011. The change in our cash balance is summarized below:

Cash balance at December 31, 2011	$ ~~435~~321,~~015~~227
Sources of cash:
Cash provided by operating activities	~~501~~1,~~456~~216,286
Total sources of cash including cash on hand	~~501~~1,~~456~~537,513
Uses of cash:
Cash used in investing activities	(~~160~~175,~~174~~885)
Cash used in financing activities	(~~392~~1,~~531~~316,947)
Total uses of cash	(~~552~~1,~~705~~492,832)
Cash balance at June 30, 2012	$ 383,766
Cash balance at September 30, 2012	$ 44,681

37Net cash provided by operating activities of $1,216,286 and $1,803,303 for the nine months ended September 30, 2012 and 2011, respectively, are attributable to our net loss adjusted for non-cash charges as presented in the consolidated statements of cash flows and changes in working capital as discussed above.

~~Net~~Through ~~cash~~September ~~provided by operating activities of $501,546 and $1,570,415 for the six months ended June~~ 30, 2012 ~~and 2011~~, ~~respectively,~~we ~~are~~have ~~attributable~~financed to our ~~net~~business ~~loss~~activities ~~adjusted~~principally ~~for~~through ~~non-cash~~issuances ~~charges~~of ascommon ~~presented~~shares, inconvertible ~~the~~promissory ~~consolidated~~notes, ~~statements~~term ofdebt, ~~cash~~and ~~flows~~lines ~~and~~of ~~changes~~credit. inThese ~~working~~financings ~~capital~~are summarized as ~~discussed above.~~follows:

Through June 30, 2012, we have financed our business activities principally through issuances of common shares, convertible promissory notes, term debt, and lines of credit. These financings are summarized as follows:


	Nine months Ended
	September 30, 2012	September 30, 2011
Proceeds from notes payable	$ 750,000	$ -
Repayment of notes payable	(780,765)	-
Proceeds from related party notes payable	-	892,261
Repayment of related party notes payable	(100,000)	(695,541)
Proceeds from line of credit	-	75,000
Repayment of line of credit	(909,744)	(379,334)
Proceeds from term debt	-	2,110,000
Repayment of term debt	-	(1,504,580)
Warrants issued for cash	-	1,000,000
Stock issued for cash, net of fees	-	2,054,889
Payment of financing fees	(60,000)	(770,000)
Payment of bond commitment fees	(216,438)	(214,951)
Net cash (used in) provided financing activities	$ (1,316,947)	$ 2,567,744

	Six Months Ended
	June 30, 2012	June 30, 2011
Proceeds from related party notes payable	$ -	$ 642,261
Repayment of related party notes payable	-	(668,541)
Proceeds from line of credit	-	75,000
Repayment of line of credit	(154,830)	(118,134)
Proceeds from term debt	750,000	1,885,000
Repayment of term debt	(711,263)	(1,229,387)
Warrants issued for cash	-	1,000,000
Stock ssued for cash, net of fees	-	2,054,889
Payment of financing fees	(60,000)	(770,000)
Payment of bond commitment fees	(216,438)	(214,951)
Net cash (used in) financing activities	$ (392,531)	$ 2,656,137

During the ~~six~~nine months ended ~~June~~September 30, 2012, and the period subsequent the Company issued 7375,~~098~~524,~~102~~666 shares of its common stock for a combination of (i) consideration for services rendered by employees, members of the Board of Directors, or external service providers, (ii) the conversion of various notes payable, and (iii) in association with a stock purchase agreement. See Note 911 for details regarding each category of share issuances. As of ~~June~~September 30, 2012, the Company had outstanding debt obligations of $109,~~390~~377,~~482~~058.

The net proceeds of debt financings were primarily used to fund our operating activities.

Our current cash and cash equivalents and ~~anticipated~~lack of cash flow from operations ~~may~~related to our curtailment of gas production and the discontinued operations of our construction services division will not be sufficient to meet our working capital, ~~capital expenditures, growth strategy~~ requirements, and debt service requirements for the foreseeable future. See “Outlook for 2012/2013 Capital” for a description of our expected capital expenditures for 2012/2013. IfWe ~~we are unable to generate revenues necessary to finance our operations over the long-term, we~~ may have to seek additional capital through the sale of our equity or borrowing. As noted in “Recent Developments,” we periodically borrow funds to finance our activities.

As discussed in the “Outlook for 2012/2013 Capital”, although it is not feasible to quantify additional capital expenditures ~~will~~ may be required during 2012 ~~for our energy construction services~~, ~~and~~we ~~repair and maintenance services segment as well as additional capital expenditures that may be required to maintain current levels of production related to our natural gas operations. We~~ will need to obtain adequate sources of cash to fund our anticipated capital expenditures through the end of 2012 to fund ongoing operations ~~and to follow through with plans for continued investments in the energy construction services business and the exploitation of our oil and gas properties~~. See Item 1A.- “Risk Factors — Risks Related to Our Business” in our Annual Report on Form 10-K for the year ended December 31, 2011 for a description of risk factors faced by the Company.

Since our inception, we have produced natural gas in the Powder River Basin located in Northeast Wyoming. Recently, we began providing construction services and repair and maintenance services primarily to the energy and energy related industries mainly located in Wyoming and North Dakota. Our strategic shift to a more balanced focus between providing goods and services has realized a more diversified revenue stream for the company. Although we maintain the strategy to seek high quality development projects in the oil and gas industry, we intend to continue our expansion into the construction services, and repair and maintenance services through growth of our existing operations. It is anticipated that the natural gas production activities combined with the services activities will impose financial requirements which will exceed our existing working capital. We may raise additional equity and/or debt capital. However, if additional financing is not available, we may be compelled to reduce the scope of our business activities through reductions in general and administrative expenses or certain asset sales.

Outlook for 2012/2013 Capital

While it has become increasingly difficult to quantify, depending on capital availability, we ~~may~~will require significant capital ~~expenditures~~ during the remainder of the fiscal year 2012, and for the subsequent periods allocated as follows:

For ~~purchases~~general ofcorporate ~~equipment for our construction services, and repair and maintenance business~~functions.

We ~~may,~~have inno ~~our~~revenue ~~discretion,~~producing ~~decide~~assets ~~to allocate resources towards other projects in addition to or in lieu of, those listed above as other opportunities arise~~ and asinsufficient ~~circumstances warrant. We currently do not have sufficient~~ working capital to fund the ~~capital~~anticipated expenditures listed above. We may, at the Company’s discretion, fund the aforementioned planned expenditures from ~~operating cash flows,~~ asset sales, potential debt and equity issuances and/or a combination of ~~all three~~both.

We expect commodity prices to be volatile, reflecting the current supply and demand fundamentals for North American natural gas and world crude oil. Political and economic events around the world, which are difficult to predict will continue to influence both oil and gas prices, while we anticipate demand for our construction and fabrication business to remain strong and pricing of our services to remain constant.

Off-Balance Sheet Arrangements

From time to time, we may enter into off-balance sheet arrangements and transactions that can give rise to off-balance sheet obligations. As of ~~June~~September 30, 2012, our off-balance sheet arrangements and transactions include operating lease agreements, bonding and gas transportation commitments. We do not believe that these arrangements are reasonably likely to materially affect our liquidity or availability of, or requirements for, capital resources.

Financial Instruments

As of ~~June~~September 30, 2012 and 2011, the Company had cash, accounts receivable, accounts payable, notes payable and accrued liabilities, which are each carried at approximate fair market value due to the short maturity date of those instruments. Unless otherwise noted, it is management’s opinion that the Company is not exposed to significant interest, currency or credit risks arising from these financial instruments.

4036

Critical Accounting Policies

Our consolidated financial statements have been prepared by management in accordance with U.S. GAAP. Please refer to the corresponding section in Part II, Item 7 and the notes to the consolidated financial statements of our Annual Report on Form10-K for the year ended ~~December31~~December 31, 2011 for the description of critical accounting policies and estimates.

Risks and Uncertainties

There are arisks ~~number~~involved in an ownership of ~~risks~~the ~~that~~Company’s ~~are~~securities. The ~~inherent~~Company inhas ~~the~~ceased ~~energy~~production ~~industry,~~of ~~particularly~~natural ingas ~~the~~and ~~segments~~impaired inall ~~which~~value related to the Company’s ~~operates. Accordingly,~~gas ~~there~~assets ~~are~~and ~~risks~~has ~~involved~~discontinued inall anoperations ~~ownership~~related ofto ~~the~~its ~~Company’s~~Energy ~~securities~~Construction Services and Repair and Maintenance Services division.

The Company has ceased production of natural gas and impaired all value related to the Companies gas assets. Our focus has become Energy Construction and Repair and Services Maintenance. The outstanding liabilities related to the Gas Production segment of the business may place to great a demand on the services segment for it to continue to exist.

For additional risk factors see “Risk Factors” in Our Annual Report on Form 10-K for the year ended December 31, 2011 for a description of the principal risks faced by us.

ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

We are a smaller reporting company as defined by Rule 12b-2 of the Securities Exchange Act of 1934 and are not required to provide the information under this item.

ITEM 4. CONTROLS AND PROCEDURES.

Disclosure Controls and Procedures

As required by Rule 13a-15 under the Securities Exchange Act of 1934 (the “1934 Act”), as of ~~June~~September 30, 2012, we carried out an evaluation of the effectiveness of the design and operation of our disclosure controls and procedures. This evaluation was carried out under the supervision and with the participation of our Chief Executive Officer (our principal executive officer) and our Chief Financial Officer (our principal financial officer). Based upon and as of the date of that evaluation, our Chief Executive Officer and Chief Financial Officer concluded that our disclosure controls and procedures were not effective as of ~~June~~September 30, 2012.

Disclosure controls and procedures are controls and other procedures that are designed to ensure that information required to be disclosed in our reports filed or submitted under the 1934 Act is recorded, processed, summarized and reported within the time periods specified in the SEC’s rules and forms. Disclosure controls and procedures include, without limitation, controls and procedures designed to ensure that information required to be disclosed in our reports filed under the 1934 Act is accumulated and communicated to our management, including our principal executive officer and our principal financial officer, as appropriate, to allow timely decisions regarding required disclosure.

41Internal Controls Over Financial Reporting and Material Weaknesses Previously Identified

~~Internal~~For ~~Controls~~the ~~Over~~year ~~Financial~~ended ~~Reporting~~December ~~and~~31, ~~Material~~2011, ~~Weaknesses~~the ~~Previously~~Company ~~Identified~~reported two material weaknesses with regard to its internal controls over Financial Reporting:

~~For the year ended December 31, 2011, the Company reported two material weaknesses with regard to its internal controls over Financial Reporting:~~ 1)

1)The Company did not have adequate procedures to completely and accurately document the elements of certain debt and equity transactions which were effected during the year by its prior management team, and

The Company did not have adequate procedures to completely and accurately document the elements of certain debt and equity transactions which were effected during the year by its prior management team, and 37

The Company simply did not have enough individuals with financial reporting experience to adequately address the unexpected lack of documentation and to prepare its financial reports on a timely basis.

A material weakness is a deficiency, or a combination of deficiencies, in internal control over financial reporting, such that there is a reasonable possibility that a material misstatement of the company's annual or interim financial statements will not be prevented or detected on a timely basis. The above material weaknesses could result in misstatements of accounting for unusual and non-routine transactions and certain financial statement accounts, including, but not limited to the aforementioned accounts and disclosures that would result in a material misstatement in the Company’s annual or interim consolidated financial statements that would not be prevented or detected in a timely manner.

Changes in Internal Controls over Financial Reporting

Remediation of Previously Identified Material Weakness

During the first quarter of 2012, ~~Management~~management was successful in substantially enhancing its documentation of debt and equity transactions; procedures were effectively put into place to eliminate this material weakness. All debt and equity transactions ~~are~~were ~~now~~ reviewed with the Company’s Chief Executive Officer who ~~makes~~made certain that all required documentation iswas available to review with the Company’s Board of Directors. Related elements of these debt and equity transactions ~~are~~were ~~now~~ documented in the minutes of the Board meetings. During the second and third quarter of fiscal 2012, due to liquidity issues our accounting staff was reduced and our utilization of consultants to supplement existing resources was also limited; therefore, as of September 30, 2012, management concludes that enhancements made during the first quarter of 2012 were negated and material weaknesses in the internal controls over financial reporting still exist.

Plan for Remediation of the Remaining Current Material Weakness

As of the close of the ~~second~~third quarter, the Company still did not ~~have~~adequate ~~enough~~resources ~~individuals~~ with financial reporting experience to adequately address the workload required to prepare its financial reports on a timely basis.

There were no other changes in our internal control over financial reporting (as defined in Rules 13a-15(f) and 15d-15(f) promulgated by the SEC under the 1934 Act) during the ~~six~~nine months ended ~~June~~September 30, 2012, that have materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.

42PART II: OTHER INFORMATION

~~PART~~ITEM ~~II:~~1 ~~OTHER~~- ~~INFORMATION~~LEGAL PROCEEDINGS

~~ITEM~~On 1approximately -June ~~LEGAL~~27, ~~PROCEEDINGS~~2011, High Plains Gas, Inc. relocated its corporate offices and warehousing facility from 3601 Southern Drive in Gillette, Wyoming to offices and warehouse facilities located at 1200 East Lincoln St., Gillette, Wyoming. The Company and the Landlord of the Southern Drive properties failed to agree upon lease terms for the previous office and warehouse location. The Company chose to relocate rather than obligate themselves to major repairs costs that were needed on the building and premises. Subsequent to the Company moving, the Landlord, Hunt Club Investment Group, LLC a Michigan limited liability company (“Hunt Club”) filed a lawsuit on July 20, 2011 in District Court in Campbell County, Wyoming. Hunt Club alleged that a lease agreement was reached between the parties and that future rents in the amount of $20,000 per month for a three year period was agreed upon. Hunt

On approximately June 27th, 2011, High Plains Gas, Inc. relocated its corporate offices and warehousing facility from 3601 Southern Drive in Gillette, Wyoming to offices and warehouse facilities located at 1200 East Lincoln St., Gillette, Wyoming. The Company and the Landlord of the Southern Drive properties failed to agree upon lease terms for the previous office and warehouse location. The Company chose to relocate rather than obligate themselves to major repairs costs that were needed on the building and premises. Subsequent to the Company moving, the Landlord, Hunt Club Investment Group, LLC a Michigan limited liability company (“Hunt Club”) filed a lawsuit on July 20th, 2011 in District Court in Campbell County, Wyoming. Hunt Club alleged that a lease agreement was reached between the parties and that future rents in the amount of $20,000 per month for a three year period was agreed upon. Hunt Club sought the principal remaining balance of $640,000 plus interest and attorney’s fees and costs in the lawsuit. A trial date had been set for February 2013. In March 2012, the Company and Hunt Club reached a settlement agreement thus terminating the lawsuit.38

OnClub ~~approximately~~sought ~~July~~the 2,principal ~~2012,~~remaining ~~High~~balance ~~Plains Gas, Inc. was named in two civil suits by the State~~ of ~~Wyoming related to unpaid personal property~~$640,000 ~~personal~~plus ~~equipment~~interest ~~taxes,~~ and ~~personal~~attorney’s ~~taxes~~fees onand ~~well~~costs ~~equipment~~in ~~for~~ the ~~fiscal periods 2007-2011~~lawsuit. A ~~The~~trial ~~two~~date ~~suits~~had ~~indicate~~been ~~damages~~set infor ~~the~~February ~~amount~~2013. In ofMarch ~~$275~~2012,~~000.~~ ~~These~~the ~~amounts~~Company ~~have~~and ~~been~~Hunt ~~accrued~~Club ~~for~~reached ina ~~accompanying~~settlement ~~balance~~agreement ~~sheets.~~thus Weterminating ~~have~~the ~~not yet responded to these suits~~lawsuit.

~~From~~On ~~time~~approximately toJuly ~~time~~2, ~~the Company may be named in claims arising in the ordinary course of business. Currently~~2012, noHigh ~~material~~Plains ~~legal proceedings or claims~~Gas, ~~other~~Inc. ~~than~~was ~~those~~named ~~disclosed~~in ~~above,~~two ~~are~~civil ~~pending~~suits ~~against~~by ~~or involve~~ the ~~Company~~State ~~that, in the opinion~~ of ~~management,~~Wyoming ~~could~~related ~~reasonably be expected~~ to ~~have~~unpaid apersonal ~~material~~property, ~~adverse~~personal ~~effect~~equipment ontaxes, ~~its business~~ and ~~financial~~personal ~~condition. Although~~taxes weon ~~are~~well ~~not~~equipment ~~party~~for tothe ~~any~~fiscal ~~material~~periods ~~litigation aside from that disclosed above, we may acquire properties with or become a party to legal actions and proceedings from time to time~~2007-2011. We ~~may~~The betwo ~~unable~~suits toindicate ~~estimate legal expenses or losses we may incur, or~~ damages ~~we may recover~~ in ~~these~~the ~~actions,~~amount ifof ~~any~~$274,828. ~~and~~These amounts have ~~not~~been accrued ~~potential~~for ~~gains or losses~~ in ~~our~~accompanying ~~financial~~balance ~~statements~~sheets. ~~Expenses~~ inWe ~~connection~~have ~~with~~not ~~these~~yet ~~actions~~responded ~~are~~to ~~recorded~~these ~~as they are incurred~~suits.

WeOn ~~believe~~May we7, ~~carry~~2013 ~~adequate~~an ~~liability~~action ~~insurance~~was filed in the District Court of Campbell County, ~~directors'~~Wyoming ~~and~~titled ~~officers'~~Pennaco ~~insurance~~Energy, ~~casualty~~Inc. ~~insurance~~v. Cep-M Purchase, ~~for~~LLC, ~~owned~~Current orEnergy ~~leased~~Partners ~~tangible~~Corporation, ~~assets~~High Plains Gas, Inc., High Plains Gas, LLC, Mark Hettinger, Jerri Hettinger, Brandon Hargett, Joseph Hettinger and ~~other~~Brent ~~insurance~~Cook as(the ~~needed~~“Pennaco toAction”). In ~~cover~~the usPennaco ~~against~~Action, ~~claims~~Pennaco alleges that at the time Current Energy Partners acquired the North and ~~lawsuits~~South Fairway Assets through CEP-M Purchase in July 2010, that ~~occur~~CEP-M Purchase had failed to comply with the terms of the purchase agreement, including without limitation payment of approximately $3,354,931 towards the original $10,570,000 purchase price. Pennaco further alleges that CEP-M Purchase had provided numerous false and/or misleading representations in the ~~ordinary~~purchase ~~course~~agreement. Pennaco alleges that Current Energy Partners guaranteed the obligations of ~~our~~CEP-M ~~business~~Purchase. ~~However,~~Pennaco anfurther ~~unfavorable~~alleges ~~resolution~~that the defaults of ~~any~~CEP-M ~~substantial~~Purchase ~~new~~and ~~matters~~Current Energy Partners has resulted in numerous further legal actions against Pennaco and others causing further damages. Pennaco further alleges that the Company as well as its operating subsidiary High Plains Gas LLC, and certain former officers and directors of the Company, are liable for the damages as “alter egos” of CEP-M Purchase and/or ~~our~~Current ~~incurrence~~Energy Partners. Pennaco also alleges that the named principals undermined the potential for success of ~~legal~~the ~~fees~~acquisition by failing to adequately finance operations, failing to provide appropriate and ~~other~~required ~~costs~~bonding, and by failing to ~~defend~~assume orcertain ~~prosecute~~contracts. Pennaco’s ~~any~~action includes breach of ~~these~~contract ~~actions~~in ~~may~~the ~~have~~purchase agreement, breach of a ~~material~~guaranty ~~adverse~~agreement, ~~effect~~breach onof ~~our~~the ~~consolidated~~implied ~~financial~~covenant ~~position~~of good faith and fair dealing, ~~results~~unjust ofenrichment, ~~operation~~conversion, fraud, negligent misrepresentation, injunctive relief, and ~~cash~~seeks ~~flows~~to inpierce athe ~~particular~~corporate ~~period~~veil with respect to the Company, its operating subsidiary and with respect to the individual defendants.

~~ITEM~~The 1ACompany –has ~~RISK~~been ~~FACTORS~~in discussions with Pennaco towards resolution of this action and is confident that a resolution can be reached. Absent such a resolution, the Company has vigorously defended this action and believes that the allegations with respect to the Company and its operating subsidiary are unfounded. The Company intends to continue to seek to reach resolution and/or vigorously defend the action.

WeFrom ~~are~~time ato ~~smaller~~time, ~~reporting~~the ~~company~~Company asmay ~~defined~~be bynamed ~~Rule~~in ~~12b-2~~claims arising in the ordinary course of business. Currently, no material legal proceedings or claims, other than those disclosed above, are pending against or involve the ~~Securities~~Company ~~Exchange~~that, ~~Act~~in the opinion of ~~1934~~management, could reasonably be expected to have a material adverse effect on its business and financial condition. Although we are not ~~required~~party to ~~provide~~any ~~the~~material ~~information~~litigation ~~under~~aside ~~this~~from ~~item~~that disclosed above, we may acquire properties with or become a party to legal actions and proceedings from time to time. We may be unable to estimate legal expenses or losses we may incur, or damages we may recover in these actions, if any, and have not accrued potential gains or losses in our financial statements. Expenses in connection with these actions are recorded as they are incurred.

43ITEM 1A – RISK FACTORS

~~ITEM~~We 2are a smaller reporting company as defined by Rule 12b-2 ~~UNREGISTERED~~of ~~SALES~~the OFSecurities ~~EQUITY~~Exchange ~~SECURITIES~~Act ~~AND~~of ~~USE~~1934 OFand ~~PROCEEDS~~are not required to provide the information under this item.

~~During the six months ended June 30, 2012, the Company issued 73,098,102 shares of its common stock as follows:~~39

·ITEM 2 - UNREGISTERED SALES OF EQUITY SECURITIES AND USE OF PROCEEDS

~~1,787,566~~During ~~shares~~the ofnine ~~common~~months ~~stock~~ended ~~were~~September ~~issued~~30, to2012, ~~external~~and ~~service~~for ~~providers~~the ~~for~~period ~~services~~subsequent ~~rendered~~the atCompany ~~values~~issued ~~between~~75,524,666 ~~$0.04~~shares ~~and~~of ~~$0.15~~its ~~per~~common ~~share.~~stock as follows:

31,~~000~~787,~~000~~566 shares of common stock were issued to aexternal ~~related~~service ~~party~~providers for services rendered asat ~~follows;~~values ~~1,000,000~~between at $0.0804 ~~per share~~ and ~~2,000,000 at~~ $0.0415 per share.

543,000,000 ~~share~~shares of common stock were issued to a related ~~parties~~party for services rendered as follows; 1,000,000 at $0.0708 per share inand ~~association with the conversion of certain promissory notes~~2,000,000 ~~which~~at ~~generated~~$0.04 aper ~~loss on conversion of debt of $1,080,000~~share.

1254,~~683~~000,~~665~~000 ~~shares~~share of common stock were issued atto ~~values~~related ~~between~~parties ~~$0.03~~at ~~and~~ $0.07 per share in association with the conversion of certain promissory notes, which generated a loss on conversion of debt of $~~216~~1,~~655~~080,000.

217,~~426~~110,~~871~~229 shares of common stock were issued at values between $0.01 and $0.07 per share in association with the conversion of certain promissory notes, which generated a ~~stock~~loss ~~purchase~~on ~~agreement~~conversion of debt of $249,682.

~~800~~2,~~000~~426,871 shares of common stock were ~~returned~~issued toat ~~treasury~~$0.07 in association with ~~the relief of an existing bonding liability. In connection therewith~~ a ~~loss~~stock ofpurchase ~~$63,746 has been recognized~~agreement.

~~ITEM 3 - DEFAULTS UPON SENIOR SECURITIES~~·

~~None~~(800,000) shares of common stock were returned to treasury in association with the relief of an existing bonding liability. In connection therewith a loss of $63,746 has been recognized.

ITEM 43 ~~–MINE~~- ~~SAFETY~~DEFAULTS ~~DISCLOSURE~~UPON SENIOR SECURITIES

~~Not Applicable~~None.

ITEM 54 -–MINE ~~OTHER~~SAFETY ~~INFORMATION~~DISCLOSURE

~~None~~Not Applicable.

44ITEM 5 - OTHER INFORMATION

~~ITEM 6 – EXHIBITS~~None.

Exhibit
No.		Description
3.1		Articles of Incorporation; filed with the Registrant’s Registration Statement on Form SB-2,May 19, 2005.
3.2		Bylaws; filed with the Registrant’s Registration Statement on Form SB-2, May 19, 2005.
3.3		Amended Articles of Incorporation – changing name from Northern Explorations, Ltd. to High Plains Gas, Inc.; filed October 6, 2010 on Form 8-K.
3.4		Unofficial restated certificate of incorporation of the registrant as amended to date filed (on April 1, 1998) as Exhibit 4.1 to registrant’s Registration Statement on Form S-8, File Number 333-49095 and hereby incorporated by reference.
3.5		By-laws of the registrant as amended effective October 14, 2005, filed (on December 12, 2005) as Exhibit 3.2 to registrant's Quarterly Report on Form 10-Q for the quarterly period ended October 31, 2005, and hereby incorporated by reference.
3.6		Certificate of Amendment to Articles of Incorporation increasing authorized common stock to 250,000,000 shares and including a class of 20,000,000 shares of Preferred Stock; filed on Form 8-K March 15, 2011.
3.7		Certificate of Amendment to Articles of Incorporation increasing authorized common stock to 500,000,000 shares and including a class of 20,000,000 shares of Preferred Stock filed as Exhibit 3.7 to registrant's Annual Report on Form 10-K for the annual period ended December 31, 2011, and hereby incorporated by reference.
4.1		High Plains Gas, Inc. 2011 Employee and Consultant Stock Option Plan; filed with Registration Statement on Form S-8 March 11, 2011.
10.1		Reorganization Agreement – between Northern Explorations, Ltd., (“NXPN”) a Nevada Corporation, and High Plains Gas, LLC, a Wyoming limited liability company (“HPG”), dated July 28, 2010; filed with the Registrant’s Current Report on Form 8-K, August 8, 2010 as Exhibit 10.1.
10.2		Amendment to the Reorganization Agreement - dated July 28, 2010, made and entered into as of September 13, 2010, by and between High Plains Gas, LLC, a Wyoming limited liability company (“HPG”), and Northern Explorations, LTD., In (“NXPN”) a Nevada Corporation; filed on Form 8-K, October 6, 2010.
10.3		Agreement – Installment or Single Payment Note, Between High Plains Gas, LLC and U.S. Bank, dated January 20,2010 as amended; filed on Form 8-K October 22, 2010.
10.4		Agreement – Mortgage Security Agreement, Financing statement and Assignment of Production, Between High Plains Gas, LLC and Jim’s Water Service, Inc.: April 6, 2010. ; filed on Form 8-K October 22, 2010.
10.5		Agreement – Master Agreement Regarding Redemption of Membership Units By High Plains Gas, LLC, Formation of M&H Resources, LLC, And Distribution And Assignment Of Certain Interests in Specific Oil and Gas Leases (the "Agreement"), effective May 5, 2010; between High Plains Gas, LLC ("HPG"), its Members; filed on Form 8-K October 22, 2010.
10.6		Agreement – Settlement and Well Buyout Agreement, Financing statement and Assignment of Production, between High Plains Gas, LLC and Alpha Wyoming Land Company, LLC; dated December 9, 2010; filed on Form 8-K October 22, 2010.
10.7		Amended and Restated Operations and Convertible Note Purchase Agreement dated as of September 30, 2010 by and among High Plains Gas, LLC, Current Energy Partners Corporation and CEP-M Purchase, LLC; filed on Form 8-K November 22, 2010.
10.8		Option Agreement dated October 31, 2010 by and between High Plains Gas, LLC, and Current Energy Partners Corporation; filed on Form 8-K November 22, 2010.

45ITEM 6 – EXHIBITS

Exhibit
No.		Description
10.9		Purchase and Sale Agreement among Current Energy Partners Corporation, CEP M Purchase LLC and Pennaco Energy, Inc. dated July 25, 2010; filed on Form 8-K December 1, 2010.
3.1		Articles of Incorporation; filed with the Registrant’s Registration Statement on Form SB-2, May 19, 2005.
10.10		Amendment dated November 24, 2010 to Option Agreement dated October 31, 2010 by and between High Plains Gas, LLC, and Current Energy Partners Corporation; filed on Form 8-K December 1, 2010.
3.2		Bylaws; filed with the Registrant’s Registration Statement on Form SB-2, May 19, 2005.
10.11		Purchase and Sale Agreement dated December 10, 2010 by and among High Plains Gas, LLC and Duramax Holdings, LLC; filed on Form 8-K December 14, 2010.
3.3		Amended Articles of Incorporation – changing name from Northern Explorations, Ltd. to High Plains Gas, Inc.; filed October 6, 2010 on Form 8-K.
10.12		Stock Purchase Agreement dated December 8, 2010 by and among High Plains Gas, LLC and Big Cat Energy Corporation; filed on Form 8-K December 15, 2010.
3.4		Unofficial restated certificate of incorporation of the registrant as amended to date filed (on April 1, 1998) as Exhibit 4.1 to registrant’s Registration Statement on Form S-8, File Number 333-49095 and hereby incorporated by reference.
10.13		Agreement between Fletcher International, Ltd. and High Plains Gas, Inc. dated as of February 24, 2011; filed on Form 8-K March 1, 2011.
3.5		By-laws of the registrant as amended effective October 14, 2005, filed (on December 12, 2005) as Exhibit 3.2 to registrant's Quarterly Report on Form 10-Q for the quarterly period ended October 31, 2005, and hereby incorporated by reference.
10.14		Warrant Certificate for Warrants to Purchase Shares of Common Stock of High Plains Gas, Inc. issued to Fletcher International, Ltd. on February 24, 2011; filed on Form 8-K March 1, 2011.
3.6		Certificate of Amendment to Articles of Incorporation increasing authorized common stock to 250,000,000 shares and including a class of 20,000,000 shares of Preferred Stock; filed on Form 8-K March 15, 2011.
10.15		Purchase and Sale Agreement between J.M. Huber Corporation and High Plains Gas, Inc. dated February 2, 2011; filed on Form 8-K March 15, 2011.
3.7		Certificate of Amendment to Articles of Incorporation increasing authorized common stock to 500,000,000 shares and including a class of 20,000,000 shares of Preferred Stock filed as Exhibit 3.7 to registrant's Annual Report on Form 10-K for the annual period ended December 31, 2011, and hereby incorporated by reference.
10.16		Credit Agreement between CEP-M Purchase, LLC, Amegy Bank National Association as Administrative Agent and Letter of Credit Issuer, and signatory lenders, dated November 19, 2010; filed on Form 8-K March 24, 2011.
4.1		High Plains Gas, Inc. 2011 Employee and Consultant Stock Option Plan; filed with Registration Statement on Form S-8 March 11, 2011.
10.17		Promissory Note issued by CEP-M Purchase, LLC to Amegy Bank National Association dated November 19, 2010; filed on Form 8-K March 24, 2011.
10.1		Reorganization Agreement – between Northern Explorations, Ltd., (“NXPN”) a Nevada Corporation, and High Plains Gas, LLC, a Wyoming limited liability company (“HPG”), dated July 28, 2010; filed with the Registrant’s Current Report on Form 8-K, August 8, 2010 as Exhibit 10.1.
10.18		Member Interest Purchase Agreement dated as of October 14, 2011 by and between Ty Miller, Levi Miller and Eric Jessen and High Plains Gas, Inc. filed as Exhibit 10.18 to registrant's Annual Report on Form 10-K for the annual period ended December 31, 2011, and hereby incorporated by reference.
10.2		Amendment to the Reorganization Agreement - dated July 28, 2010, made and entered into as of September 13, 2010, by and between High Plains Gas, LLC, a Wyoming limited liability company (“HPG”), and Northern Explorations, LTD., In (“NXPN”) a Nevada Corporation; filed on Form 8-K, October 6, 2010.
10.19		Employment Agreement between High Plains Gas, Inc. and Ty Miller dated November 10, 2011 filed as Exhibit 10.19 to registrant's Annual Report on Form 10-K for the annual period ended December 31, 2011, and hereby incorporated by reference.
10.3		Agreement – Installment or Single Payment Note, Between High Plains Gas, LLC and U.S. Bank, dated January 20,2010 as amended; filed on Form 8-K October 22, 2010.
10.20		Employment Agreement between High Plains Gas, Inc. and Levi 1Miller dated November 10, 2011 filed as Exhibit 10.20 to registrant's Annual Report on Form 10-K for the annual period ended December 31, 2011, and hereby incorporated by reference.
10.4		Agreement – Mortgage Security Agreement, Financing statement and Assignment of Production, Between High Plains Gas, LLC and Jim’s Water Service, Inc.: April 6, 2010. ; filed on Form 8-K October 22, 2010.
10.21		Employment Agreement between High Plains Gas, Inc. and Eric Jessen dated November 10, 2011 filed as Exhibit 10.21 to registrant's Annual Report on Form 10-K for the annual period ended December 31, 2011, and hereby incorporated by reference.
10.5		Agreement – Master Agreement Regarding Redemption of Membership Units By High Plains Gas, LLC, Formation of M&H Resources, LLC, And Distribution And Assignment Of Certain Interests in Specific Oil and Gas Leases (the "Agreement"), effective May 5, 2010; between High Plains Gas, LLC ("HPG"), its Members; filed on Form 8-K October 22, 2010.
10.22		Convertible Promissory Note (one) dated November 18, 2011 issued by High Plains Gas, Inc. to Ty Miller, Levi Miller and Eric Jessen filed as Exhibit 10.22 to registrant's Annual Report on Form 10-K for the annual period ended December 31, 2011, and hereby incorporated by reference.
10.6		Agreement – Settlement and Well Buyout Agreement, Financing statement and Assignment of Production, between High Plains Gas, LLC and Alpha Wyoming Land Company, LLC; dated December 9, 2010; filed on Form 8-K October 22, 2010.
10.23		Convertible Promissory Note (two) dated November 18, 2011 issued by High Plains Gas, Inc. to Ty Miller, Levi Miller and Eric Jessen filed as Exhibit 10.23 to registrant's Annual Report on Form 10-K for the annual period ended December 31, 2011, and hereby incorporated by reference.
10.7		Amended and Restated Operations and Convertible Note Purchase Agreement dated as of September 30, 2010 by and among High Plains Gas, LLC, Current Energy Partners Corporation and CEP-M Purchase, LLC; filed on Form 8-K November 22, 2010.
10.24		Stock Option Agreement dated as of November 18, 2011 between High Plains Gas, Inc. and Ty Miller filed as Exhibit 10.24 to registrant's Annual Report on Form 10-K for the annual period ended December 31, 2011, and hereby incorporated by reference.
10.8		Option Agreement dated October 31, 2010 by and between High Plains Gas, LLC, and Current Energy Partners Corporation; filed on Form 8-K November 22, 2010.

4641

Exhibit
No.		Description
10.25		Stock Option Agreement dated as of November 18, 2011 between High Plains Gas, Inc. and Levi Miller filed as Exhibit 10.25 to registrant's Annual Report on Form 10-K for the annual period ended December 31, 2011, and hereby incorporated by reference.
10.9		Purchase and Sale Agreement among Current Energy Partners Corporation, CEP M Purchase LLC and Pennaco Energy, Inc. dated July 25, 2010; filed on Form 8-K December 1, 2010.
10.26		Stock Option Agreement dated as of November 18, 2011 between High Plains Gas, Inc. and Eric Jessen filed as Exhibit 10.26 to registrant's Annual Report on Form 10-K for the annual period ended December 31, 2011, and hereby incorporated by reference.
10.10		Amendment dated November 24, 2010 to Option Agreement dated October 31, 2010 by and between High Plains Gas, LLC, and Current Energy Partners Corporation; filed on Form 8-K December 1, 2010.
10.27		Lockup Agreement dated as of November 18, 2011 between High Plains Gas, Inc. and Ty Miller, Levi Miller and Eric Jessen filed as Exhibit 10.27 to registrant's Annual Report on Form 10-K for the annual period ended December 31, 2011, and hereby incorporated by reference.
10.11		Purchase and Sale Agreement dated December 10, 2010 by and among High Plains Gas, LLC and Duramax Holdings, LLC; filed on Form 8-K December 14, 2010.
10.28		Security Agreement by CEP-M Purchase, LLC in favor of Amegy Bank National Association as Collateral Agent dated November 19, 2010; filed on Form 8-K March 24, 2011.
10.12		Stock Purchase Agreement dated December 8, 2010 by and among High Plains Gas, LLC and Big Cat Energy Corporation; filed on Form 8-K December 15, 2010.
10.29		Mortgage, Security Agreement, Financing Statement and Assignment of Production from CEP-M Purchase, LLC to Amegy Bank National Association as Collateral Agent effective November 19, 2010; filed on Form 8-K March 24, 2011.
10.13		Agreement between Fletcher International, Ltd. and High Plains Gas, Inc. dated as of February 24, 2011; filed on Form 8-K March 1, 2011.
10.30		Employment Agreement between the Company and Mark D. Hettinger dated as of January 1, 2011; filed on Form 10-K for the Fiscal Year ended December 31, 2010 on April 18, 2011.
10.14		Warrant Certificate for Warrants to Purchase Shares of Common Stock of High Plains Gas, Inc. issued to Fletcher International, Ltd. on February 24, 2011; filed on Form 8-K March 1, 2011.
10.31		Employment Agreement between the Company and Brent M. Cook dated as of January 1, 2011; filed on Form 10-K for the Fiscal Year ended December 31, 2010 on April 18, 2011.
10.15		Purchase and Sale Agreement between J.M. Huber Corporation and High Plains Gas, Inc. dated February 2, 2011; filed on Form 8-K March 15, 2011.
10.32		Employment Agreement between the Company and Joseph Hettinger dated as of January 1, 2011; filed on Form 10-K for the Fiscal Year ended December 31, 2010 on April 18, 2011.
10.16		Credit Agreement between CEP-M Purchase, LLC, Amegy Bank National Association as Administrative Agent and Letter of Credit Issuer, and signatory lenders, dated November 19, 2010; filed on Form 8-K March 24, 2011.
10.33		Employment Agreement between the Company and Brandon Hargett dated as of January 1, 2011; filed on Form 10-K for the Fiscal Year ended December 31, 2010 on April 18, 2011.
10.17		Promissory Note issued by CEP-M Purchase, LLC to Amegy Bank National Association dated November 19, 2010; filed on Form 8-K March 24, 2011.
10.34		Amendment No. 7 to the Purchase and Sale Agreement between J.M. Huber Corporation and High Plains Gas, Inc. effective as of May 3, 2011; filed on Form 8-K May 6, 2011.
10.18		Member Interest Purchase Agreement dated as of October 14, 2011 by and between Ty Miller, Levi Miller and Eric Jessen and High Plains Gas, Inc. filed as Exhibit 10.18 to registrant's Annual Report on Form 10-K for the annual period ended December 31, 2011, and hereby incorporated by reference.
10.35		Amendment No. 8 to the Purchase and Sale Agreement between J.M. Huber Corporation and High Plains Gas, Inc. effective as of May 31, 2011; filed on Form 8-K June 2, 2011.
10.19		Employment Agreement between High Plains Gas, Inc. and Ty Miller dated November 10, 2011 filed as Exhibit 10.19 to registrant's Annual Report on Form 10-K for the annual period ended December 31, 2011, and hereby incorporated by reference.
10.36		Amendment No. 9 to the Purchase and Sale Agreement between J.M. Huber Corporation and High Plains Gas, Inc. effective as of June 30, 2011; filed on Form 8-K June 30, 2011.
10.20		Employment Agreement between High Plains Gas, Inc. and Levi 1Miller dated November 10, 2011 filed as Exhibit 10.20 to registrant's Annual Report on Form 10-K for the annual period ended December 31, 2011, and hereby incorporated by reference.
10.37		Amendment to Convertible Promissory Notes dated March 29, 2012 between High Plains Gas, Inc. and Ty Miller, Levi Miller and Eric Jessen filed as Exhibit 10.37 to registrant's Annual Report on Form 10-K for the annual period ended December 31, 2011, and hereby incorporated by reference.
10.21		Employment Agreement between High Plains Gas, Inc. and Eric Jessen dated November 10, 2011 filed as Exhibit 10.21 to registrant's Annual Report on Form 10-K for the annual period ended December 31, 2011, and hereby incorporated by reference.
10.38		Debt Conversion Agreement dated as of March 29, 2012 between High Plains Gas, Inc. and Ty Miller filed as Exhibit 10.38 to registrant's Annual Report on Form 10-K for the annual period ended December 31, 2011, and hereby incorporated by reference.
10.22		Convertible Promissory Note (one) dated November 18, 2011 issued by High Plains Gas, Inc. to Ty Miller, Levi Miller and Eric Jessen filed as Exhibit 10.22 to registrant's Annual Report on Form 10-K for the annual period ended December 31, 2011, and hereby incorporated by reference.
10.39		Debt Conversion Agreement dated as of March 29, 2012 between High Plains Gas, Inc. and Levi Miller filed as Exhibit 10.39 to registrant's Annual Report on Form 10-K for the annual period ended December 31, 2011, and hereby incorporated by reference.
10.23		Convertible Promissory Note (two) dated November 18, 2011 issued by High Plains Gas, Inc. to Ty Miller, Levi Miller and Eric Jessen filed as Exhibit 10.23 to registrant's Annual Report on Form 10-K for the annual period ended December 31, 2011, and hereby incorporated by reference.
10.40		Securities Purchase Agreement dated as of March 9, 2012 by and between High Plains Gas, Inc. and Tonaquint, Inc.; filed on Form 8-K April 4, 2012.
10.24		Stock Option Agreement dated as of November 18, 2011 between High Plains Gas, Inc. and Ty Miller filed as Exhibit 10.24 to registrant's Annual Report on Form 10-K for the annual period ended December 31, 2011, and hereby incorporated by reference.

4742

Exhibit
No.		Description
10.41		Secured Convertible Promissory Note issued on March 9, 2012 by High Plains Gas, Inc. to Tonaquint, Inc. ; filed on Form 8-K April 4, 2012.
10.25		Stock Option Agreement dated as of November 18, 2011 between High Plains Gas, Inc. and Levi Miller filed as Exhibit 10.25 to registrant's Annual Report on Form 10-K for the annual period ended December 31, 2011, and hereby incorporated by reference.
10.42		Warrant to Purchase Shares of Tonaquint issued on March 9, 2012 by High Plains Gas, Inc. to Tonaquint, Inc. ; filed on Form 8-K April 4, 2012.
10.26		Stock Option Agreement dated as of November 18, 2011 between High Plains Gas, Inc. and Eric Jessen filed as Exhibit 10.26 to registrant's Annual Report on Form 10-K for the annual period ended December 31, 2011, and hereby incorporated by reference.
10.43		Security Agreement dated as of March 9, 2012 by and among High Plains Gas, Inc., Miller Fabrication, LLC and Tonaquint, Inc. ; filed on Form 8-K April 4, 2012.
10.27		Lockup Agreement dated as of November 18, 2011 between High Plains Gas, Inc. and Ty Miller, Levi Miller and Eric Jessen filed as Exhibit 10.27 to registrant's Annual Report on Form 10-K for the annual period ended December 31, 2011, and hereby incorporated by reference.
10.44		Guaranty dated as of March 9, 2012 by and between Miller Fabrication, Inc. and Tonaquint, Inc.; filed on Form 8-K April 4, 2012.
10.28		Security Agreement by CEP-M Purchase, LLC in favor of Amegy Bank National Association as Collateral Agent dated November 19, 2010; filed on Form 8-K March 24, 2011.
10.45		Amendment No. 1 to the Member Interest Purchase Agreement dated November 17, 2011 by and between Ty Miller, Levi Miller and Eric Jessen and High Plains Gas, Inc. filed as Exhibit 10.45 to registrant's Annual Report on Form 10-K for the annual period ended December 31, 2011, and hereby incorporated by reference.
10.29		Mortgage, Security Agreement, Financing Statement and Assignment of Production from CEP-M Purchase, LLC to Amegy Bank National Association as Collateral Agent effective November 19, 2010; filed on Form 8-K March 24, 2011.
10.46		on Form 10-K for the annual period ended December 31, 2011, and hereby incorporated by reference.
10.30		Employment Agreement between the Company and Mark D. Hettinger dated as of January 1, 2011; filed on Form 10-K for the Fiscal Year ended December 31, 2010 on April 18, 2011.
21		Subsidiaries of registrant; filed on registrant's Annual Report on Form 10-K for the annual period ended December 31, 2010, and hereby incorporated by reference.
10.31		Employment Agreement between the Company and Brent M. Cook dated as of January 1, 2011; filed on Form 10-K for the Fiscal Year ended December 31, 2010 on April 18, 2011.
31.1*		Certification of the Chief Executive Officer of Competitive Technologies, Inc. pursuant to Section 302 of the Sarbanes-Oxley Act of 2002 (Rule 13a-14(a) or Rule 15d-14(a)).
10.32		Employment Agreement between the Company and Joseph Hettinger dated as of January 1, 2011; filed on Form 10-K for the Fiscal Year ended December 31, 2010 on April 18, 2011.
31.2*		Certification of the Chief Financial Officer of Competitive Technologies, Inc. pursuant to Section 302 of the Sarbanes-Oxley Act of 2002 (Rule 13a-14(a) or Rule 15d-14(a)).
10.33		Employment Agreement between the Company and Brandon Hargett dated as of January 1, 2011; filed on Form 10-K for the Fiscal Year ended December 31, 2010 on April 18, 2011.
32.1*		Certification of the Chief Executive Officer of Competitive Technologies, Inc. pursuant to Section 906 of the Sarbanes-Oxley Act of 2002 (18 U.S.C. 1350) (furnished herewith).
10.34		Amendment No. 7 to the Purchase and Sale Agreement between J.M. Huber Corporation and High Plains Gas, Inc. effective as of May 3, 2011; filed on Form 8-K May 6, 2011.
32.2*		Certification of the Chief Financial Officer of Competitive Technologies, Inc. pursuant to Section 906 of the Sarbanes-Oxley Act of 2002 (18 U.S.C. 1350) (furnished herewith).
10.35		Amendment No. 8 to the Purchase and Sale Agreement between J.M. Huber Corporation and High Plains Gas, Inc. effective as of May 31, 2011; filed on Form 8-K June 2, 2011.
101**		Interactive Data Files.
10.36		Amendment No. 9 to the Purchase and Sale Agreement between J.M. Huber Corporation and High Plains Gas, Inc. effective as of June 30, 2011; filed on Form 8-K June 30, 2011.
10.37		Amendment to Convertible Promissory Notes dated March 29, 2012 between High Plains Gas, Inc. and Ty Miller, Levi Miller and Eric Jessen filed as Exhibit 10.37 to registrant's Annual Report on Form 10-K for the annual period ended December 31, 2011, and hereby incorporated by reference.
10.38		Debt Conversion Agreement dated as of March 29, 2012 between High Plains Gas, Inc. and Ty Miller filed as Exhibit 10.38 to registrant's Annual Report on Form 10-K for the annual period ended December 31, 2011, and hereby incorporated by reference.
10.39		Debt Conversion Agreement dated as of March 29, 2012 between High Plains Gas, Inc. and Levi Miller filed as Exhibit 10.39 to registrant's Annual Report on Form 10-K for the annual period ended December 31, 2011, and hereby incorporated by reference.
10.40		Securities Purchase Agreement dated as of March 9, 2012 by and between High Plains Gas, Inc. and Tonaquint, Inc.; filed on Form 8-K April 4, 2012.

* Furnished herewith43

** To be filed by amendmentSIGNATURES

48Pursuant 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~~Dated: March 28, 2014

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

~~Dated:~~(the ~~August 31, 2012~~registrant)

~~HIGH~~By: ~~PLAINS~~\s\ ~~GAS,~~Edward ~~INC.~~Presley

~~(the~~Edward ~~registrant)~~Presley

~~By:~~Chief ~~\s\~~Executive ~~Brandon Hargett~~Officer

~~Brandon~~By: ~~Hargett~~\s\ Edward Presley

~~Chief~~Edward ~~Executive Officer~~Presley

~~By:~~Chief ~~\s\~~Financial ~~Brandon Hargett~~Officer

~~Brandon Hargett~~44

Chief Financial Officer

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