XOTC:HPGS High Plains Gas Inc Quarterly Report 10-Q Filing - 6/30/2012

Effective Date 6/30/2012

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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 30, 2012

or

[  ]  

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

[hpgs10q2q2012august312012001.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

(Address of principal executive offices)

(Zip Code)


 

(307) 686-5030

 

(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

 

 

 

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 28, 2012 was 348,812,512 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

29

Item 3.

Quantitative and Qualitative Disclosures About Market Risk

35

Item 4.

Controls and Procedures

35

 

 

 

PART II – OTHER INFORMATION

 

 

 

 

Item 1.

Legal Proceedings

37

Item 1A

Risk Factors

37

Item 2.

Unregistered Sales of Equity Securities and Use of Proceeds

37

Item 3.

Default upon Senior Securities

38

Item 4.

Mine Safety Disclosures

38

Item 5.

Other Information

38

Item 6.

Exhibits

39

 

 

 

SIGNATURES

43



3









HIGH PLAINS GAS, INC.

CONDENSED CONSOLIDATED BALANCE SHEETS

JUNE 30, 2012 AND DECEMBER 31, 2011


 

June 30, 2012

 

December 31, 2011

 

(Unaudited)

 

 

ASSETS

 

 

 

Current Assets:

 

 

 

Cash and cash equivalents

$

383,766 

 

$

435,015 

Accounts receivable, net

1,804,305 

 

4,055,189 

Deferred financing fees, net

103,844 

 

89,905 

Rebates receivable, accounts receivable sales

276,661 

 

Bond commitment fees, net

140,959 

 

100,140 

Funds in escrow

 

750,000 

Commodity hedge

1,094,602 

 

2,182,400 

Prepaid and other

239,384 

 

99,766 

Total current assets

4,043,521 

 

7,712,415 

 

 

 

 

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 

 

2,293,292 

Certificates of deposit – restricted

201,988 

 

201,988 

Other Assets-net

3,724,730 

 

7,647,166 

Total Assets

$

10,261,859 

 

$

31,597,794 

 

 

 

 

LIABILITIES AND STOCKHOLDERS’ (DEFICIT)

 

 

 

Current Liabilities:

 

 

 

Accounts payable and accrued liabilities

$

19,819,400 

 

$

16,314,313 

Current portion-term debt

961,848 

 

1,889,809 

Current portion - lines of credit

6,102,786 

 

6,240,563 

Notes payable – related parties

1,593,950 

 

3,423,837 

Total current liabilities

28,477,984 

 

27,868,522 

 

 

 

 

Notes Payable – related parties

1,900,000 

 

3,000,000 

Debt Obligations – term debt, net of current

371,898 

 

414,651 

Asset Retirement Obligation

9,679,815 

 

9,320,074 

Total liabilities

40,429,697 

 

40,603,247 

 

 

 

 

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 

Common stock - $.001 par value: 500,000,000  authorized;   348,812,512 and 275,714,410  issued and outstanding, respectively

348,812 

 

275,714 

Additional paid in capital

61,151,460 

 

53,229,680 

Accumulated (deficit)

(92,479,081)

 

(63,321,818)

Total stockholders’  (deficit)

(30,167,838)

 

(9,005,453)

Total Liabilities and Stockholders’  (Deficit)

$

10,261,859 

 

$

31,597,794 




4





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 30, 2012 AND 2011

(UNAUDITED)


 

For The Three Months Ended June 30,

 

2012

 

2011

Revenues

 

 

 

Natural gas revenue

$

619,542 

 

$

3,379,997 

Service revenue

5,628,374 

 

Total Revenue

6,247,916 

 

3,379,997 

 

 

 

 

Costs and Expenses

 

 

 

Lease operating expense and production taxes

2,496,361 

 

3,166,764 

Cost of services

5,389,391 

 

General and administrative expense

2,444,931 

 

4,021,289 

Depreciation, depletion and amortization

1,021,173 

 

1,364,096 

Other operating expenses

581,292 

 

234,347 

Amortization of bond commitment / financing fees

35,832 

 

742,262 

Realized commodity hedge (gain)

(1,072,170)

 

(56,760)

Impairment of  natural gas properties

12,953,082 

 

4,125,010 

Impairment expense - intangibles

3,604,645 

 

Accretion of asset retirement obligation

172,468 

 

219,224 

Total Costs and Expenses

27,627,005 

 

13,816,232 

 

 

 

 

Operating (Loss)

(21,379,089)

 

(10,436,235)

 

 

 

 

Other Income (Expense)

 

 

 

Other income (expense)

13,653 

 

54,275 

(Loss) on valuation of equity securities

 

(890,257)

Unrealized commodity hedge gain (loss)

(1,460,312)

 

392,699 

(Loss) on extinguishment of debt

(37,181)

 

(532,932)

Interest (expense)

(450,418)

 

(392,251)

Total Other Income (Expense)

(1,934,258)

 

(1,368,466)

 

 

 

 

Net (Loss)

$

(23,313,347)

 

$

(11,804,701)

 

 

 

 

Preferred stock dividend

(36,405)

 

 

 

 

 

Net (Loss) applicable to common stockholders

(23,276,942)

 

$

(11,804,701)

 

 

 

 

Net (Loss) per share

$

(0.07)

 

$

(0.07)

 

 

 

 

Weighted average number of common shares outstanding – basic and diluted

347,646,363 

 

167,314,447 


See accompanying notes to these unaudited condensed consolidated financial statements



5





HIGH PLAINS GAS, INC.

CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS

FOR THE SIX MONTH SENDED JUNE 30, 2012 AND 2011

(UNAUDITED)


 

For The Six Months Ended June 30,

 

2012

 

2011

Revenues

 

 

 

Natural gas revenue

$

2,143,458 

 

$

7,407,081 

Service revenue

12,038,509 

 

Total Revenue

14,181,967 

 

7,407,081 

 

 

 

 

Costs and Expenses

 

 

 

Lease operating expense and production taxes

4,561,739 

 

7,292,902 

Cost of services

11,536,832 

 

General and administrative expense

5,603,875 

 

6,276,985 

Depreciation, depletion and amortization

1,971,347 

 

3,347,365 

Other operating expenses

581,292 

 

673,517 

Amortization of bond commitment / financing fees

231,954 

 

1,595,430 

Realized commodity hedge (gain)

(1,806,696)

 

(208,505)

Impairment of  gas properties

13,440,869 

 

4,125,010 

Impairment expense - intangibles

3,604,645 

 

Accretion of asset retirement obligation

359,741 

 

388,746 

Total Costs and Expenses

40,085,598 

 

23,491,450 

 

 

 

 

Operating (Loss)

(25,903,631)

 

(16,084,369)

 

 

 

 

Other Income (Expense)

 

 

 

Other income (expense)

(244,516)

 

61,143 

(Loss) on valuation of equity securities

-- 

 

(893,506)

Unrealized commodity hedge (loss)

(1,087,799)

 

(28,215)

Loss on extinguishment of debt

(1,289,299)

 

(532,932)

Interest (expense)

(648,290)

 

(1,305,445)

Total Other Income (Expense)

(3,269,904)

 

(2,698,955)

 

 

 

 

Net (Loss)

$

(29,173,535)

 

$

(18,783,324)

 

 

 

 

Preferred stock dividend

(56,575)

 

 

 

 

 

Net (Loss) applicable to common stockholders

(29,116,960)

 

$

(18,783,324)

 

 

 

 

Net (Loss) per share

$

(0.09)

 

$

(0.11)

 

 

 

 

Weighted average number of common shares outstanding – basic and diluted

316,097,089 

 

161,911,391 


See accompanying notes to these unaudited condensed consolidated financial statements


 

 

 

 





6









7





HIGH PLAINS GAS, INC.

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOW

FOR THE SIX MONTHS ENDED JUNE 30, 2012 AND 2011

(UNAUDITED)

 

For the Six Months ended June 30,

 

2012

 

2011

Cash Flows from Operating Activities:

 

 

 

Net (loss)

$

(29,173,535)

 

$

(18,783,324)

Adjustments to reconcile net (loss) to net cash provided by (used) in operating activities:

 

 

 

Depletion, depreciation and amortization

1,971,347 

 

3,347,365 

Accretion of asset retirement obligation

359,741 

 

388,746 

Amortization of bond commitment and finance fees

231,954 

 

2,050,538 

Amortization of debt discount

17 

 

Unrealized commodity hedge (gain) / loss

 

28,215 

Stock and warrant based compensation

2,021,778 

 

253,054 

Stock issued for services

313,454 

 

813,004 

Stock issued for commitment fee

166,663 

 

Impairment of oil and gas prospects

13,440,869 

 

4,125,010 

Impairment of intangible assets

3,604,645 

 

Loss on fair value of securities

 

893,506 

Loss on conversion of bonding liability

63,646 

 

Loss on debt conversion

145,653 

 

532,932 

Loss on debt conversion related party

1,080,000 

 

Proceeds from the sale of accounts receivable

5,937,800 

 

Repayments of accounts receivable sold

(4,370,054)

 

 

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 in prepaid and other assets

532,084 

 

85,402 

Rebates receivable – accounts receivable sales

(276,661)

 

Increase in accounts payables and accrued liabilities

3,768,917 

 

8,166,873 

Net cash provided by operating activities

501,456 

 

1,570,415 

Cash Flows from Investing Activities:

 

 

 

Additions to oil and gas properties

(11,424)

 

(623,931)

Deposits on acquisition of oil and gas property

 

(2,000,000)

Purchase of equipment

(148,750)

 

(546,839)

Net cash (used in) investing activities

(160,174)

 

(3,170,770)

Cash Flows from Financing Activities:

 

 

 

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 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

(392,531)

 

2,656,137 

 

 

 

 

Net Increase in Cash and Cash Equivalents

(51,249)

 

1,055,782 

 

 

 

 

Cash and Equivalents, at beginning of period

435,015 

 

208,823 

 

 

 

 

Cash and Equivalents, at end of period

$

383,766 

 

$

1,264,605 


See accompanying notes to these unaudited condensed consolidated financial statements



8





HIGH PLAINS GAS, INC.

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOW

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

(UNAUDITED)


 

For the Six Months Ended June 30,

 

2012

 

2011

Supplemental Cash Information:

 

 

 

Cash paid for interest

$

324,539 

 

$

883,204

 

 

 

 

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

Discount on convertible notes recorded to additional paid in capital

$

836,000 

 

$

-

Common stock issued in connection with prepaid services

$

438,608 

 

$

-

Common stock issued in connection with settlement of accounts payable

$

41,511 

 

$

-

Common stock issued in connection with conversion of notes payable

$

892,981 

 

$

-

Dividends declared on Series A Convertible Preferred Stock

$

56,575 

 

$

-

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



9





HIGH PLAINS GAS, INC.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

June 30, 2012


NOTE 1:  ORGANIZATION


High Plains Gas, Inc. (“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 a 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 and have no immediate plans to resume production.


NOTE 2:  BASIS OF PRESENTATION AND SIGNIFICANT ACCOUNTING 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 the accompanying unaudited financial statements.  Operating results for the periods presented are not necessarily indicative of the results that may be expected for the full year.  These financial statements should be read in conjunction with the financial statements and footnotes which are included as part of the Company’s Form 10-K for the year ended December 31, 2011.


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 in technical default of certain covenants contained in its credit and loan agreement with its primary lender. The holder of the promissory note under the credit and loan agreement may at its option give notice to the Company that the amount is immediately due and payable. As a result, $6.0 million of the Company’s long-term debt has been classified as a current liability in the accompanying unaudited balance sheet at June 30, 2012.


The Company’s recurring 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.


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


Business Segment Information. The Company is comprised of two operating segments: (1) Natural Gas Production and (2) Energy Construction Services, and Repair and Maintenance Services.  The unaudited



10





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.


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.


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



11





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 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 per common share.  We do not report fully diluted loss per common share as the effect would be anti-dilutive.


NOTE 3:  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 in June, 2012 and has no definitive plans to resume production in the foreseeable future.


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.



12






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

 

 

 

 

 

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)

 

-

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)

 

3,226,838

Total

$

43,533,233

 

$

(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

 

 

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

 

$

43,533,233


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



13





and $4,125,010 and $4,125,010, respectively.  Impairment charges relate to the Company’s unevaluated leasehold costs, shut in drilling equipment, and evaluated shut in equipment.


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 30, 2012 and 2011 were not significant.


NOTE 4:  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,

 

2012

 

2011

 

 

 

 

Asset retirement obligations, beginning of period

$

9,320,074

 

$

8,229,630

Revisions in estimated liabilities

-

 

-

Accretion expense

359,741

 

388,746

Asset retirement obligations, end of period

$

9,679,815

 

$

8,618,736


NOTE 5:  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

 

 

 

 

Transportation and vehicles

$

1,314,744 

 

$

1,076,949 

Equipment and other

1,265,704 

 

1,311,161 

Computer and software

423,069 

 

313,346 

Total Cost

3,003,517 

 

2,701,456 

Accumulated depreciation

(711,897)

 

(408,164)

Property and equipment, net

$

2,291,620 

 

$

2,293,292 


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.





14





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.




15





NOTE 7:  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).


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.





16









17





NOTE 8:  INTANGIBLE ASSETS


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


 

 

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



Amortization expense 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.


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 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 30,



18





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.


·

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.


·

54,000,000 share of common stock were issued to related parties at $0.07 per share in association with the conversion of certain promissory notes, which generated a loss on conversion of debt of $1,080,000.


·

12,683,665 shares of common stock were issued at values between $0.03 and $0.07 per share in association with the conversion of certain promissory notes, which generated a loss on conversion of debt of $216,655.


·

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


·

(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.


Preferred Stock


As of June 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


Common Stock Options


During the six months ended June 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 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.




19





A summary of the activity through June 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 exercisable – June 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 months ended June 30, 2012 and 2011the Company recognized $1,499,450 and $nil in share-based compensation respectively related to these issuances. As of June 30, 2012, there was $8,946,269 in deferred share-based compensation expense related to the unvested portion of the options.




20









21





Warrants


During the six months ended June 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 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

(250,000)

 

$0.50

Expired during period

-

 

-

 

 

 

 

Warrants outstanding – June 30, 2012

9,559,306

 

$0.33

Warrants exercisable – June 30, 2012

9,399,306

 

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




22





At June 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 11:  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 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

Current Portion

 

 

 

Amegy Bank (a)

$

6,000,000

 

$

6,000,000

First National Bank of Gillette (b)

102,786

 

225,439

Bank of the West Reserve (c)

--

 

15,124

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 30, 2012).  Outstanding principal balances and any related accrued interest is 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 30, 2012, the outstanding principal balance was $6,000,000.  The credit facility is subject to restrictive covenants, and as of June 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 June 30, 2012 and December 31, 2011due to the failure to maintain compliance with these covenants.




23





(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 30, 2012 was $102,786.


(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

Current Portion

 

 

 

US Bank (a)

$

590,407

 

$

659,107

Ford Motor Credit (b)

8,761

 

9,325

Term Notes Various (d)

1,020,463

 

885,000

Trade Term Notes Various (e)

178,200

 

336,377

Total Current Portion

1,797,831

 

1,889,809

Debt Discount (d)

(835,983)

 

-

Current Portion, net

$

961,848

 

$

1,889,809

Related Party

 

 

 

Term Notes Related Party (f)

$

393,950

 

$

423,837

Miller Group (c)

1,200,000

 

3,000,000

Total Current Portion Related Party

$

1,593,950

 

$

3,423,837

 

 

 

 

Long Term Portion

 

 

 

US Bank (a)

$

-

 

$

16,935

Ford Motor Credit (b)

17,142

 

20,642

Term Notes Various (d)

11,000

 

-

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

$

4,827,696

 

$

8,728,297


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


2012

$

2,858,188

2013

 

2,514,742

2014

 

151,496

2015

 

77,416

2016

 

58,903

2017

 

2,934

Total

$

5,663,679



24





(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.


(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.


(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 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 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 30, 2012 $54,463 in principal remains outstanding related to this note. Two conversions related to this note were recorded during the quarter ended June 30, 2012 a total of $45,537 in principal and $5,463 were converted into 1,800,000 shares of our common stock.



25





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


Two additional notes payable, totaling $200,000 issued in August 2011 with maturities of July through September 2011. Remaining principal balances of $25,000 and $90,000 are past due, notes payable bear interest at 0% per annum and are unsecured.


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.  


(e)

Between October 2011 and February 2012, the Company acquired or entered into various term note agreements including:


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 bearing interest at 15% per annum. This note is past due as of June 30, 2012.


·

A note payable in the amount of $61,027 bearing interest at 0% per annum.  This note is past due as of June 30, 2012


·

A note payable in the amount of $122,240 per annum bearing interest at 0% due and payable as of December 31, 2012.


·

A note payable in the amount of $50,000 bearing interest at 10%.  This note is past due as of June 30, 2012.


·

A note payable in the amount of $25,000 bearing interest at 0% per annum.  This note is past due as of June 30, 2012.


NOTE 12:  OTHER FINANCING ARRANGEMENTS


During 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.  As of June 30, 2012, the Miller



26





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 months ended June 30, 2012 totaled $318,000 and $176,000 for the year ended December 31, 2011.  As of June 30, 2012, $58,000 remains in accounts payable.


·

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


·

During the six months ended June 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 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 months ended June 30, 2012, these expenses totaled $144,831, of which $13,467 remains in accounts payable as of June 30, 2012.


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


NOTE 14:  SEGMENT REPORTING


In 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.  Based on this evaluation, the Company has identified two reportable operating segments which are (1) Natural Gas Production segment and (2) the energy construction and maintenance services segment.  The Company considers its gathering and marketing functions as ancillary to the natural gas activities and thus they do not collectively form a reportable operating segment.  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.


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).




27







 

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



28





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 



29





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 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 is 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.


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


During the six months ended June 30, 2012, the Company recognized $1,806,696 of realized net gains and ($1,087,799) in unrealized losses related to our hedging arrangement.  During the six months ended June 30, 2011, we recognized $208,505 in realized gains as well as ($28,215) of unrealized losses related to our hedging arrangement.


On or about August 15, 2012 the Company entered into a 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 ($113,248) as of June 30, 2012 and adjusted the market value of the hedge to reflect the terminal value of all payments to be received subsequent to June 30, 2012.  This amount of $1,094,602 has been recorded as a current asset on our unaudited condensed consolidated balance sheet as of June 30, 2012.



NOTE 18:  COMMITMENTS AND CONTINGENCIES


Operating leases


The Company is currently renting office and manufacturing space at various locations under non-cancelable operating leases extending through 2016.  Future minimum operating lease payments with initial terms of one year or more are as follows:




30






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


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

Commitment ($/month)

Firm Transport

 

WC

 

CIG – Rocky Mountains

 

$65,433

 

November 2015


High Plains Gas, Inc. shut in its gas producing assets in May 2012, the Company is assessing the 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.




31





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 months ended June 30, 2012 and 2011 totaled $nil and $585,227, respectively.


NOTE 20:  SUBSEQUENT EVENTS


Pursuant to FASB ASC 855 “Subsequent Events”, management has evaluated all events and transactions that occurred from June 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 or about August 15, 2012 the Company entered into a transaction, termination and liquidation agreement whereby its hedging arrangement (Note 17) was terminated. In connection therewith the Company recorded a realized loss 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.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).



32





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., (“High Plains Gas”) is a provider of goods and services to regional end markets serving the energy industry.  We produce natural gas in the Powder River Basin located in Northeast Wyoming.  We provide 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 very important strategic shift to expand into the energy construction services, and repairs and maintenance services through growth of our existing operations.


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


Energy Construction, Repair and Maintenance Services


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



33





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 primary operations of our Natural Gas Production attempts to seek profitability in existing natural gas production programs through existing fields.  Substantially all of this segment’s revenues are generated through the sale of natural gas at market prices and the settlement of commodity hedges.  


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 months ended June 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 30, 2012 Compared to Three Months Ended June 30, 2011


During the three months ended June 30, 2012, oil and gas revenues decreased to $619,542, from $3,379,997 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 Mcf for the three months ended June 30, 2012 from 1,008 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 and our curtailment of production in May, 2012


During the three months ended June 30, 2012, service revenue totaled $5,628,374 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 three months ended June 30, 2012, we incurred lease operating expense and production taxes of $2,496,361 as compared to $3,166,764 in the prior period.  Increases in lease operating expenses and related taxes resulted from charges related to accelerated accrued capital expenditures offset by decreases in production volumes offset by curtailment of production in May, 2012.


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.


During the three months ended June 30, 2012, general and administrative expense decreased to $2,444,931compared to $4,021,289 in the corresponding prior period.  General and administrative expense for the three months ended June 30, 2012 was composed primarily of salaries and wages of $445,859, consulting fees of $328,635, and legal and accounting fees of $426,741.  Non-cash stock-based



34





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.



35






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 30, 2012, we had a working capital deficit of $24,434,463 compared to $20,156,107 at December 31, 2011.


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


Cash balance at December 31, 2011

$

435,015 

Sources of cash:

 

Cash provided by operating activities

501,456 

Total sources of cash including cash on hand

501,456 

 

 

Uses of cash:

 

Cash used in investing activities

(160,174)

Cash used in financing activities

(392,531)

Total uses of cash

(552,705)

 

 

Cash balance at June 30, 2012

$

383,766 



37





Net cash provided by operating activities of $501,546 and $1,570,415 for the six months ended June 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.


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:


 

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 months ended June 30, 2012, the Company issued 73,098,102 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 9 for details regarding each category of share issuances.  As of June 30, 2012, the Company had outstanding debt obligations of $10,390,482.


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


Our current cash and cash equivalents and anticipated cash flow from operations may 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. If 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 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.




38









39





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 require significant capital expenditures during the remainder of the fiscal year 2012, allocated as follows:


·

For purchases of equipment for our construction services, and repair and maintenance business.


We may, in our discretion, decide to allocate resources towards other projects in addition to or in lieu of, those listed above as other opportunities arise and as circumstances warrant. We currently do not have sufficient working capital to fund the capital 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.

 

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 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 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.




40





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, 2011 for the description of critical accounting policies and estimates.


Risks and Uncertainties


There are a number of risks that are inherent in the energy industry, particularly in the segments in which the Company operates.  Accordingly, there are risks involved in an ownership of the Company’s securities.


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 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 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.




41





Internal Controls Over Financial Reporting and Material Weaknesses Previously Identified


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


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


2)

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 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 now reviewed with the Company’s Chief Executive Officer who makes certain that all required documentation is available to review with the Company’s Board of Directors.  Related elements of these debt and equity transactions are now documented in the minutes of the Board meetings.


Plan for Remediation of the Remaining Current Material Weakness


As of the close of the second quarter, the Company still did not have enough 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 months ended June 30, 2012, that have materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.





42





PART II: OTHER INFORMATION


ITEM 1 - LEGAL PROCEEDINGS


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.


On approximately July 2, 2012, High Plains Gas, Inc. was named in two civil suits by the State of Wyoming related to unpaid personal property, personal equipment taxes, and personal taxes on well equipment for the fiscal periods 2007-2011. The two suits indicate damages in the amount of $275,000. These amounts have been accrued for in accompanying balance sheets. We have not yet responded to these suits.


From time to time, the Company may be named in 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 Company that, in the opinion of management, could reasonably be expected to have a material adverse effect on its business and financial condition.  Although we are not party to any material litigation aside from 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.


We believe we carry adequate liability insurance, directors' and officers' insurance, casualty insurance, for owned or leased tangible assets, and other insurance as needed to cover us against claims and lawsuits that occur in the ordinary course of our business.  However, an unfavorable resolution of any substantial new matters, and/or our incurrence of legal fees and other costs to defend or prosecute any of these actions may have a material adverse effect on our consolidated financial position, results of operation and cash flows in a particular period.



ITEM 1A – RISK FACTORS


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.





43





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


During the six months ended June 30, 2012, the Company issued 73,098,102 shares of its common stock 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.


·

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


·

54,000,000 share of common stock were issued to related parties at $0.07 per share in association with the conversion of certain promissory notes, which generated a loss on conversion of debt of $1,080,000.


·

12,683,665 shares of common stock were issued at values between $0.03 and $0.07 per share in association with the conversion of certain promissory notes, which generated a loss on conversion of debt of $216,655.


·

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


·

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 3 - DEFAULTS UPON SENIOR SECURITIES

None.



ITEM 4 –MINE SAFETY DISCLOSURE


Not Applicable.



ITEM 5 - OTHER INFORMATION


None.




44





ITEM 6 – EXHIBITS


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.



45






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.

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.

10.11

 

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.

10.12

 

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.

10.13

 

Agreement between Fletcher International, Ltd. and High Plains Gas, Inc. dated as of February 24, 2011; filed on Form 8-K March 1, 2011.

10.14

 

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.

10.15

 

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.

10.16

 

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.

10.17

 

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.

10.18

 

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.

10.19

 

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.

10.20

 

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.

10.21

 

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.

10.22

 

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.

10.23

 

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.

10.24

 

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.



46






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.

10.26

 

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.

10.27

 

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.

10.28

 

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.

10.29

 

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.

10.30

 

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.

10.31

 

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.

10.32

 

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.

10.33

 

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.

10.34

 

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.

10.35

 

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.

10.36

 

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.



47






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.

10.42

 

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.

10.43

 

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.

10.44

 

Guaranty dated as of March 9, 2012 by and between Miller Fabrication, Inc. and Tonaquint, Inc.; filed on Form 8-K April 4, 2012.

10.45

 

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.

10.46

 

on Form 10-K for the annual period ended December 31, 2011, and hereby incorporated by reference.

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.

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)).

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)).

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).

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).

101**

 

Interactive Data Files.


* Furnished herewith

** To be filed by amendment



48





SIGNATURES


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



Dated: August 31, 2012


HIGH PLAINS GAS, INC.

(the registrant)


By: \s\ Brandon Hargett

Brandon Hargett

Chief Executive Officer


By: \s\ Brandon Hargett

Brandon Hargett

Chief Financial Officer




49



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