Galaxy Energy 10-Q 2007 Q3 Quarterly report

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 August 31, 2007

[  ]           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 1-32682

GALAXY ENERGY CORPORATION

(Exact name of registrant as specified in its charter)

Colorado (State or other jurisdiction of incorporation or organization) 98-0347827  (IRS Employer Identification No.)

1331 – 17th Street, Suite 1050, Denver, Colorado 80202

(Address of principal executive offices)           (Zip Code)

(303) 293-2300

(Registrant’s telephone number, including area code)

Not applicable

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

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

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, or a non-accelerated filer.  See definition of “accelerated filer and large accelerated filer” in Rule 12b-2 of the Exchange Act.  (Check one):

Large accelerated filer[  ]                                        Accelerated filer[  ]                               Non-accelerated filer[x]

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

Indicate the number of shares outstanding of each of the issuer’s classes of common stock, as of the latest practicable date: 83,661,968 shares of Common Stock, $0.001 par value, as of October 11, 2007

GALAXY ENERGY CORPORATION

(A Development Stage Company)

CONSOLIDATED BALANCE SHEETS

	August 31, 2007 (unaudited)			November 30, 2006
ASSETS
Current assets
Cash and cash equivalents	$	52,170		$	608,180
Accounts receivable, joint interest		16,914			60,475
Accounts receivable, joint interest, related party		95,309			923,172
Accounts receivable, other		11,624			102,800
Prepaid and other		116,726			107,236
Total Current Assets		292,743			1,801,863
Oil and gas properties, at cost, full cost method of accounting
Unevaluated oil and gas properties		43,254,484			42,767,330
Evaluated oil and gas properties		13,013,975			10,991,945
Less accumulated depletion, amortization and impairment		(13,013,975	)		(8,966,135	)
		43,254,484			44,793,140
Furniture and equipment, net		71,141			121,945
Other assets
Deferred financing costs, net		423,391			565,524
Restricted investments		428,261			459,783
Other		61,303			18,003
		912,955			1,043,310
Total Assets	$	44,531,323		$	47,760,258

LIABILITIES AND STOCKHOLDER’S EQUITY

Current liabilities
Accounts payable and accrued expenses	$	1,506,654		$	1,548,168
Accounts payable – related party		49,413			64,400
Current portion convertible notes payable, net					10,019,996
Notes payable – related party		2,049,728			7,549,728
Interest payable		755,399			2,488,451
Total Current liabilities		4,361,194			21,670,743
Non-current obligations
Convertible notes payable, net		24,764,284			16,308,801
Notes payable – related party		14,118,777
Interest payable		3,763,957			572,466
Interest payable – related party		929,386
Asset retirement obligation		1,913,815			1,288,337
Total Non-current obligations		45,490,219			18,169,604
Stockholders’ equity (deficit)
Preferred stock, $001 par value; Authorized – 25,000,000shares; Issued – none
Common stock, $.001 par value; Authorized – 400,000,000shares;Issued and outstanding – 83,661,968 shares and 81,661,968 shares		83,662			81,662
Capital in excess of par value		72,837,413			71,537,766
Deficit accumulated during the development stage		(78,241,164	)		(63,699,517	)
Total Stockholders’ equity (deficit)		(5,320,089	)		7,919,911
Total Liabilities and Stockholders’ Equity (deficit)	$	44,531,323		$	47,760,258

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

2

GALAXY ENERGY CORPORATION

(A Development Stage Company)

CONSOLIDATED STATEMENTS OF OPERATIONS

Unaudited

	Three Months Ended August 31,
	2007			2006
Revenue
Natural gas sales	$	76,303		$	281,559
		76,303			281,559
Operating expenses
Lease operating expense		445,817			189,493
General and administrative		761,617			1,172,301
Impairment of oil and gas properties		2,370,880			1,031,160
Depreciation, depletion and amortization		232,056			318,379
		3,810,370			2,711,333
Other income (expense)
Interest and other income		4,749			3,283
Interest expense and financing costs		(2,044,630	)		(3,970,113	)
		(2,039,881	)		(3,966,830	)
Net Loss	$	(5,773,948	)	$	(6,396,604	)
Net loss per common share – basic & diluted	$	(.07	)	$	(.09	)
Weighed average number of common shares outstanding - basic and diluted		83,661,968			70,536,771

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

3

GALAXY ENERGY CORPORATION

(A Development Stage Company)

CONSOLIDATED STATEMENTS OF OPERATIONS

Unaudited

	Nine Months Ended August 31,						From Inception (June 18, 2002) to
	2007			2006			August 31, 2007
Revenue
Natural gas sales	$	447,232		$	955,895		$	3,061,523
Gain on disposition of oil and gas property								197,676
Gain on disposition of oil and gas property and other income, related party								122,946
		447,232			955,895			3,382,145
Costs and expenses
Lease operating expense		704,151			590,311			2,509,602
General and administrative		2,801,617			3,652,158			19,887,519
Impairment of oil and gas properties		3,866,195			1,031,160			10,534,191
Depreciation, depletion and amortization		511,168			680,707			3,254,763
		7,883,131			5,954,336			36,186,075
Other income (expense)
Interest and other income		14,043			12,588			244,344
Interest expense and financing costs		(7,119,791	)		(12,918,109	)		(45,681,578	)
		(7,105,748	)		(12,905,521	)		(45,437,234	)
Net Loss		(14,541,647	)		(17,903,962	)		(78,241,164	)
Net loss per common share – basic and diluted		(.17	)		(.26	)		(1.45	)
Weighed average number of common shares Outstanding – basic and diluted		83,321,309			69,290,943			54,119,024

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

4

GALAXY ENERGY CORPORATION

(A Development Stage Company)

CONSOLIDATED STATEMENTS OF CASH FLOWS

Unaudited

	Nine Months Ended August 31,						Cumulative From Inception (June 18, 2002) to
	2007			2006			August 31, 2007
Cash flows from operating activities
Net loss	$	(14,541,647	)	$	(17,903,962	)	$	(78,241,164	)
Adjustments to reconcile net loss to net cash usedby operating activities
Stock for interest					45,913			4,352,508
Stock for services								264,600
Stock for services – related party								90,000
Oil and gas properties for services								732,687
Stock for debt – related party								233,204
Amortization of discount and deferred financing costs on convertible debt		2,738,126			8,849,726			20,646,688
Deferred selling costs		410,000						410,000
Finance costs incurred for waiver of triggering event								3,457,101
Write-off of discount and deferred financing costsupon conversion of convertible debt					346,083			2,979,404
Write-off of discount and deferred financing costsupon extinguishment of convertible debt								2,162,597
Compensation expense on vested stock options		891,647			999,660			2,619,057
Depreciation, depletion and amortization and aaccretion of ARO expense		262,582			680,707			3,001,176
Gain on disposition of oil and gas assets								(270,389	)
Impairment of oil and gas properties		3,866,195			1,031,160			10,534,191
Other								11,178
Changes in assets and liabilities
Accounts payable – trade, accruals, bank overdrafts		(41,515	)		3,025,023			513,410
Accounts payable – related party		(14,987	)		(3,259	)		49,413
Interest payable		2,387,825			1,363,098			5,448,742
Accounts receivable, prepaid and other current assets		953,110			(1,729,278	)		(234,666	)
Other		(43,300	)		2,642			(61,743	)
Net cash used by operating activities		(3,131,964	)		(3,292,487	)		(21,302,006	)
Cash flows from investing activities
Additions to oil and gas properties		(1,967,853	)		(2,817,603	)		(47,908,147	)
Management fees earned on operating properties		56,303			1,506,394			1,752,133
Purchase of furniture and equipment		(2,289	)		(232	)		(283,461	)
Purchase surety bonds					(80,000	)		(459,783	)
Proceeds from surety bonds		31,521						31,521
Proceeds from sale of oil and gas asset								340,000
Deposit on oil and gas property sale, net of sellingcosts
Advance to affiliated								(60,000	)
Cash received upon recapitalization and merger								4,234
Net cash (used for) investing activities		(1,882,318	)		(1,391,441	)		(46,583,503	)

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

5

GALAXY ENERGY CORPORATION

(A Development Stage Company)

CONSOLIDATED STATEMENTS OF CASH FLOWS

Unaudited

	Nine Months Ended August 31,						Cumulative From Inception (June 18, 2002) to
	2007			2006			August 31, 2007
Cash flows from financing activities
Proceeds from sale of common stock								17,905,300
Proceeds from sale of convertible notes payable					7,000,000			44,695,000
Proceeds from sale of convertible debentures								5,040,000
Proceeds from sale on notes payable – related party		8,618,777						14,118,777
Proceeds from exercise of warrants								1,019,306
Debt and stock offering costs					(127,700	)		(3,980,569	)
Payment of convertible notes payable		(4,160,505	)		(3,333,333	)		(10,180,285	)
Payment of note payable – related party					(16,909	)		(129,578	)
Payment of note payable								(550,272	)
Net cash provided by financing activities		4,458,272			3,522,058			67,937,679
Net (decrease) increase in cash		(556,010	)		(1,161,870	)		52,170
Cash and cash equivalents, beginning of period		608,180			1,328,469
Cash and cash equivalents, end of period	$	52,170		$	166,599		$	52,170
Supplemental schedule of cash flow information
Cash paid for interest	$	1,585,045		$	2,238,288		$	6,144,329
Supplemental disclosures of non-cash investing and financing activities
Debt incurred for oil and gas properties	$			$			$	3,646,000
Debt incurred for finance costs	$			$			$	3,547,101
Stock issued for services	$			$			$	354,600
Stock issued for interest and debt	$			$	3,076,780		$	13,742,538
Stock issued for convertible debentures	$			$			$	5,640,000
Warrants issued for offering and financing costs	$			$	27,274		$	1,685,850
Discount on convertible debt issued	$			$	566,540		$	14,883,630
Conversion of interest to debt	$			$			$	11,178
Stock issued for subsidiary – related	$			$			$	(202,232	)
Stock issued for oil and gas properties	$			$			$	9,146,800
Stock issued in connection with oil and gas asset sale	$	410,000		$			$	410,000

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

6

GALAXY ENERGY CORPORATION

(A Development Stage Company)

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

NOTE 1 - ORGANIZATION

Galaxy Energy Corporation is an independent oil and gas company primarily engaged in the exploration for, and the acquisition and development of crude oil and natural gas.  These activities have been conducted primarily in the Rocky Mountain region of the United States.

The unaudited financial statements included herein were prepared from the records of the Company in accordance with generally accepted accounting principles in the United States applicable to interim financial statements and reflect all adjustments which are, in the opinion of management, necessary to provide a fair statement of the results of operations and financial position for the interim periods.  Such financial statements conform to the presentation reflected in the Company’s Form 10-K filed with the Securities and Exchange Commission for the year ended November 30, 2006.  The current interim period reported herein should be read in conjunction with the Company’s Form 10-K for the year ended November 30, 2006.

The results of operations for the nine months ended August 31, 2007 are not necessarily indicative of the results that may be expected for the full fiscal year ending November 30, 2007.

NOTE 2 - SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

BASIS OF PRESENTATION

The accompanying consolidated financial statements include the Company and its wholly owned subsidiaries, Dolphin Energy Corporation (“Dolphin”) and Pannonian International, Ltd.  (“Pannonian”). All significant intercompany transactions have been eliminated.

LIQUIDITY

During the nine months ended August 31, 2007, the Company incurred a net loss of approximately $14,542,000 and used cash for operating activities of approximately $3,132,000.  The Company also has a working capital deficit of approximately $4,000,000, a stockholders’ deficit of approximately $5,300,000 and debt due to debt holders of approximately $56,000,000 that is payable over the next 3 years.  These matters raise substantial doubt about the Company’s ability to continue as a going concern.  The Company’s continued operation is contingent upon its ability to raise additional capital, and ultimately attaining profitability from its oil and gas operations.

On December 29, 2006, the Company entered into a Purchase and Sale Agreement with a related party to sell all of the Company’s oil and gas interests in the Powder River Basin of Wyoming and Montana (the “Powder River Basin Assets”).  The purchase price for the Powder River Basin Assets was $45 million, with $20 million to be paid in cash and $25 million to be paid in shares of the purchaser’s common stock.  The purchase and sale agreement expired on August 31, 2007 and was not extended.

The Company is currently searching for other buyers and suitable terms for a sale of some of its assets; however there is no assurance a sale will be completed or that the Company will realize the full carrying value of the assets.  In such an event, the Company may be required to write off a portion of the carrying value and such write-off could be material.

Any financing obtained through the sale of Company equity will likely result in substantial dilution to the Company’s stockholders. 

7

GALAXY ENERGY CORPORATION

(A Development Stage Company)

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

NOTE 2 - SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (continued)

DEVELOPMENT STAGE

The Company is considered a development stage company as defined by Statement of Financial Accounting Standards (“SFAS”) No. 7, and its principal activities since inception have been raising capital through the sale of common stock and convertible notes and the acquisition of oil and gas properties in the Western United States, Germany and Romania.  The Company has recorded limited production from wells in the Powder River Basin of Wyoming and the Piceance Basin of Colorado; however, management does not consider that the Company has commenced principal operations as of August 31, 2007.

USE OF ESTIMATES

The preparation of financial statements in conformity with generally accepted accounting principles requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and reported amounts of revenues and expenses during the reporting period.  Actual results could differ from those estimates.

The Company’s financial statements are based on a number of significant estimates, including oil and gas reserve quantities, which are the basis for the calculation of depreciation, depletion and impairment of oil and gas properties, and timing and costs associated with its retirement obligation.  In addition, significant estimates are required in the valuation of undeveloped oil and gas properties.  Actual results could differ from those estimates and such differences could be material.

The oil and gas industry is subject, by its nature, to environmental hazards and clean-up costs.  At this time, management knows of no substantial costs from environmental accidents or events for which the Company may be currently liable.  In addition, the Company’s oil and gas business makes it vulnerable to changes in wellhead prices of crude oil and natural gas.  Such prices have been volatile in the past and can be expected to be volatile in the future.  By definition, proved reserves are based on current oil and gas prices and estimated reserves.  Price declines reduce the estimated quantity of proved reserves and increase annual amortization expense (which is based on proved reserves).

OIL AND GAS PROPERTIES

The Company utilizes the full cost method of accounting for oil and gas activities.  Under this method, subject to a limitation based on estimated value, all costs associated with property acquisition, exploration and development, including costs of unsuccessful exploration, are capitalized within a cost center.  No gain or loss is recognized upon the sale or abandonment of undeveloped or producing oil and gas properties unless: 1) the sale represents a significant portion of oil and gas properties within a cost center and the gain significantly alters the relationship between capitalized costs and proved oil and gas reserves of the cost center; or 2) the proceeds of the sale are in excess of the capitalized costs within the cost center.  Depreciation, depletion and amortization of oil and gas properties is computed on the units of production method based on proved reserves.  Amortizable costs include estimates of future development costs of proved undeveloped reserves.

8

GALAXY ENERGY CORPORATION

(A Development Stage Company)

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

NOTE 2 - SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (continued)

OIL AND GAS PROPERTIES (Continued)

Capitalized costs of oil and gas properties may not exceed an amount equal to the present value, discounted at 10%, of the estimated future net cash flows from proved oil and gas reserves plus the cost, or estimated fair market value, if lower, of unproved properties.  Should capitalized costs exceed this ceiling, an impairment is recognized.  The present value of estimated future net cash flows is computed by applying year end prices of oil and natural gas to estimated future production of proved oil and gas reserves as of year end, less estimated future expenditures to be incurred in developing and producing the proved reserves and assuming continuation of existing economic conditions.  As of August 31, 2007, based upon natural gas prices of $2.32 per mcf, the full cost pool exceeded the above-described ceiling by $2,370,880.  Accordingly, impairment expense of $2,370,880 was recorded for the three months ended August 31, 2007.  The Company had previously recorded $1,495,315 in impairment expense in quarter ended May 31, 2007.  At August 31, 2007, the Company’s net full cost pool after these impairments is zero.

Unevaluated properties are assessed periodically on a cost center basis and costs associated with any properties determined to be impaired are reclassified to evaluated properties and such costs are added to the amortization base, which is subject to the full cost ceiling test limitations as described above.  Approximately $2,000,000 of no impairment or reclassification of unevaluated property costs was recognized during the nine months ended August 31, 2007.

IMPAIRMENT

The Company applies SFAS 144, “Accounting for the Impairment and Disposal of Long-Lived Assets,” which requires that long-lived assets to be held and used be reviewed for impairment whenever events or changes in circumstances indicate that the carrying amount of an asset may not be recoverable.  Oil and gas properties accounted for using the full cost method of accounting, the method utilized by the Company, are excluded from this requirement, but will continue to be subject to the ceiling test limitations as described above.

DEFERRED SELLING COSTS

In connection with the proposed sale of the Powder River Basin Assets, the Company has incurred certain costs, which totaled $461,895, and were recorded as Deferred Selling Costs.  These costs were expensed as the sale to the related party was not completed.

ASSET RETIREMENT OBLIGATION

In 2001, the FASB issued SFAS 143, “Accounting for Asset Retirement Obligations.”  SFAS 143 addresses financial accounting and reporting for obligations associated with the retirement of tangible long-lived assets and the associated asset retirement costs.  This statement requires companies to record the present value of obligations associated with the retirement of tangible long-lived assets in the period in which it is incurred.  The liability is capitalized as part of the related long-lived asset’s carrying amount.  Over time, accretion of the liability is recognized as an operating expense and the capitalized cost is depreciated over the expected useful life of the related asset.  The Company’s asset retirement obligations (“ARO”) relate primarily to the plugging, dismantlement, removal, site reclamation and similar activities of its oil and gas properties.

9

GALAXY ENERGY CORPORATION

(A Development Stage Company)

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

NOTE 2 - SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (continued)

ASSET RETIREMENT OBLIGATION (Continued)

The Company has, through acquisition and drilling, acquired working interests in 243 natural gas wells.  A limited number of these wells have had initial gas production, and the others are in various stages of completion and hook up at August 31, 2007.  The Company adopted the provisions of SFAS 143 to record the ARO associated with all wells in which the Company owns an interest on the date such obligation arose.  Depreciation of the related asset, and accretion of the ARO on wells from which production has commenced, has been calculated on a unit of production basis.  The amounts recognized upon adoption are based upon numerous estimates and assumptions, including future retirement costs, future recoverable quantities of oil and gas, future inflation rates and the credit-adjusted risk-free interest rate.

The Company evaluated the liability associated with its asset retirement obligations and determined that due to its inability to place certain of these assets into service that the liability at August 31, 2007 for approximately 145 wells should equal its estimated plugging and abandonment cost.  The Company recorded an additional $543,025 in liability and ARO asset.

The information below reflects the change in the ARO during the periods ended August 31,

	2007		2006
Balance beginning of period	$	1,288,337	$	1,242,967
Liabilities incurred		-		52,975
Revisions		543,025		(106,878	)
Liabilities settled		-		-
Accretion		82,453		66,724
Balance end of period	$	1,913,815	$	1,255,788

SHARE BASED COMPENSATION

Effective December 1, 2005, the Company adopted SFAS 123(R),  “Accounting for Stock-Based Compensation,” using the modified prospective method, which results in the provisions of SFAS 123(R) being applied to the consolidated financial statements on a going-forward basis.  Prior periods have not been restated.  SFAS 123(R) requires companies to recognize share-based payments to employees as compensation expense on a fair value method.  Under the fair value recognition provisions of SFAS 123(R), stock-based compensation cost is measured at the grant date based on the fair value of the award and is recognized as expense over the service period, which generally represents the vesting period.  The expense recognized over the service period is required to include an estimate of the awards that will be forfeited.  Previously, no such forfeitures have occurred.  The Company is assuming no forfeitures going forward based on the Company's historical forfeiture experience.  The fair value of stock options is calculated using the Black-Scholes option-pricing model.

10

GALAXY ENERGY CORPORATION

(A Development Stage Company)

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

NOTE 2 - SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (continued)

SHARE BASED COMPENSATION (Continued)

As of August 31, 2007, options to purchase an aggregate of 4,955,000 shares of the Company's common stock were outstanding, of which 3,632,500 are exercisable.  These options were granted during 2007, 2006, 2005, and 2004, to the Company’s employees, directors and consultants at exercise prices ranging from $0.19 to $3.51 per share.  The options vest at varying schedules within five years of their grant date and typically expire within ten years from the grant date.  Stock-based compensation costs were $891,647 and $999,660, before tax, for the nine months ended August 31, 2007 and 2006, respectively.  These amounts were charged to operations as compensation expense and included within general and administrative expense.

(LOSS) PER COMMON SHARE

Basic (loss) per share is based on the weighted average number of common shares outstanding during the period.  Diluted (loss) per share reflects the potential dilution that could occur if securities or other contracts to issue common stock were exercised or converted into common stock.  Convertible equity instruments such as stock options, warrants, convertible debentures and notes payable are excluded from the computation of diluted loss per share, as the effect of the assumed exercises would be anti dilutive.

RECLASSIFICATION

Certain amounts in the financial statements have been reclassified to conform to the August 31, 2007 financial statement presentation.  The reclassifications have no effect on the Company's net loss for the period.

NOTE 3 – PROPERTY AND EQUIPMENT

OIL AND GAS PROPERTIES

The Company recognizes three cost centers for its oil and gas activities, the United States Cost Center, the Germany Cost Center and the Romania Cost Center.

United States Cost Center

In 2003, the Company began the acquisition of unevaluated oil and gas properties primarily in the Powder River Basin region of the Rocky Mountain area.  In 2004, the Company acquired additional unevaluated properties, began its exploration program by drilling 135 wells and commenced limited production of natural gas in the Powder River Basin.  During 2005, exploratory drilling activities continued in the Powder River Basin, development of certain areas commenced and natural gas production reached a level that allowed the Company to recognize proved reserves on those producing properties.  During 2006 and to date, the Company continues limited dewatering operations in the Powder River Basin.

In 2005, the Company entered into an exploration project in the Piceance Basin of northwestern Colorado, acquiring prospective acreage, evaluating and planning for an exploratory drilling program. In 2006, the Company, as operator, drilled four wells and participated as non-operator in the drilling of four additional wells in the Piceance basin.  As of August 31, 2007, three of the Company’s operated wells are shut in pending completion operations and three of the non-operated wells have commenced production of natural gas, condensate and other hydrocarbon liquids.

11

GALAXY ENERGY CORPORATION

(A Development Stage Company)

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

NOTE 3 – PROPERTY AND EQUIPMENT (continued)

OIL AND GAS PROPERTIES (Continued0

As of August 31, 2007, based upon natural gas prices of $2.32 per mcf, all of Galaxy’s properties were not economic.  Additionally, the Company impaired certain of its unproved acreage totalling $2,000,000.  Such costs were transferred to the full cost pool.  Accordingly impairment expense of $2,370,880 was recorded for the three months ended August 31, 2007. The Company had previously recorded $1,495,315 in impairment expense in quarter ended May 31, 2007.  Following the ceiling test write downs, the Company’s balance sheet reflects no capitalized oil and gas costs for the United States cost center.

Germany Cost Center

In March 2005, the Company, through its wholly owned subsidiary, Pannonian, entered into a farmout agreement with an unrelated party (the “Farmee”) to conduct exploration activities on its Neues Bergland Exploration Permit in Germany.  Prior to the farmout Pannonian owned a 50% interest in the permit.  Under the terms of the agreement, the Farmee made an initial payment of $750,000 to Pannonian and its partners to acquire a 40% interest in the permit, thereby reducing Pannonian’s ownership interest to 30%. The Company recognized a gain of $197,676 on the transaction, representing the excess of the proceeds over the original cost of the property.  In December 2005, the Company commenced drilling the initial test well on the permit.  The well, in which the Company had a carried interest, was completed in January 2006.  In July 2006, the Company completed the testing of the four primary zones of interest in the Glantal-1 well and no significant natural gas flows were encountered.  The wellbore was plugged and abandoned in August 2006.  The Company and its joint venture partners are evaluating further operations on the permit, which could include a seismic program and additional exploratory drilling.  The Company’s balance sheet reflects no capitalized oil and gas costs related to the Germany cost center

Romania Cost Center

In May 2005, the Company, through its wholly owned subsidiary, Pannonian, entered into a farmout agreement with a related party whose President is a significant shareholder of the Company (Falcon Oil & Gas or “Falcon”) to evaluate the concession held by Pannonian in the Jiu Valley Coal Basin in Romania.  This concession had been assigned to Pannonian by the Romanian government, in October 2002, under the terms of a Concession Agreement (the “Concession”).  The farmout agreement calls for the assignment of the Concession to Falcon; the assignment of a 75% working interest in the Concession area; and for the drilling of one test well and an additional, optional, test well, the cost of which will be paid 100% by Falcon.  In addition Falcon paid Pannonian $100,000 upon approval by the Romanian government of the assignment of the Concession, and will pay the first $250,000 of Pannonian’s proportionate share of drilling and operating costs subsequent to the drilling of the first two wells.  The Company recognized a gain of $72,713 on the transaction, representing the excess of the proceeds over the original cost of the property.  The first test well on the property, in which the Company had a carried interest, was drilled in 2005 and completion testing was carried out in 2006.  Based upon the completion test results , the partners in the project determined to plug and abandon the well.  The Company and Falcon are evaluating whether the drilling of a second well should be commenced in 2007.  Following the recognition of the gain on farmout, the Company’s balance sheet reflects no capitalized oil and gas costs for the Romanian cost center.

12

GALAXY ENERGY CORPORATION

(A Development Stage Company)

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

NOTE 4 - NOTES PAYABLE

RELATED PARTIES

As of August 31, 2007, the Company has issued eleven separate subordinated unsecured promissory notes for a total of $11,625,000 in favor of Bruner Family Trust UTD March 28, 2005, (the “Bruner Trust”) a related party. One of the trustees of the Bruner Trust is Marc E. Bruner, the president and a director of the Company.  Interest accrues at the rate of 8% per annum and the notes mature as summarized below or the time at which the Company’s senior indebtedness has been paid in full.  As the senior indebtedness is scheduled for repayment on May 31, 2010, the related party notes are classified as non-current obligations as of August 31, 2007.

In connection with the acquisition of oil and gas properties from DAR LLC, (“DAR”) the Company issued a promissory note to DAR in the amount of $2,600,000.  At August 31, 2007, the remaining balance of the note payable was $2,049,728.  The note together with accrued interest was acquired by the Bruner Trust in October 2006. The note, in the amount of $2,049,728 accrues interest at the rate of 12% per annum.  While the note, as amended, has a stated maturity date of December 1, 2006, the Bruner Family Trust has stated that it will not enforce its rights under the note until November 30, 2007.

At August 31, 2007 and November 30, 2006, notes payable to the Bruner Trust are as follows:

Issue Date	Due Date	August 31, 2007	November 30, 2006
Current liabilities
January 14, 2004	November 30, 2007	$                       2,049,728	$                           2,049,728
Non-current obligations
September 28, 2006	January 26, 2007	$                       2,500,000	$                           2,500,000
November 1, 2006	March 1, 2007	1,000,000	1,000,000
November 13, 2006	March 13, 2007	500,000	500,000
November 30, 2006	March 30, 2007	1,500,000	1,500,000
February 1, 2007	June 1, 2007	500,000	-
February 26, 2007	June 26, 2007	900,000	-
March 30, 2007	July 28, 2007	1,350,000	-
April 25, 2007	August 23, 2007	1,200,000	-
May 4, 2007	September 1, 2007	450,000	-
May 31, 2007	September 28, 2007	600,000	-
June 29, 2007	October 27, 2007	750,000
August 22, 2007	December 20, 2007	125,000
August 29, 2007	December 27, 2007	250,000
		$                     1,625,000	$                      5,500,000

Subsequent to August 31, 2007 and through the date of the filing of this report, the Company has borrowed an additional $975,000 from the Bruner Trust, under the same terms and conditions as the other notes.

13

GALAXY ENERGY CORPORATION

(A Development Stage Company)

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

NOTE 4 - NOTES PAYABLE (Continued)

On December 29, 2006, the Company entered into a Purchase and Sale Agreement (PSA) with a related party (PetroHunter Energy Corporation) to sell all of the Company’s oil and gas interests in the Powder River Basin of Wyoming and Montana (the “Powder River Basin Assets”).  The purchase price for the Powder River Basin Assets was $45 million, with $20 million to be paid in cash and $25 million to be paid in shares of the purchaser’s common stock.  The sale was not completed.

As part of the PSA, PetroHunter was required and did make an initial earnest money payment of $1.4 million.  PetroHunter made an additional earnest money payment of $600,000 in January 2007. Furthermore, PetroHunter paid the company $243,777 in March 2007 and $250,000 in July 2007 to cover operating expenses since January 1, 2007 of the fields covered by the PSA.  Since the sale was not completed, these deposits and advances have converted into a promissory note, payable to PetroHunter, and are unsecured subordinated debt of the Company, which is payable only after repayment of our senior indebtedness.  Interest on the note accrues at the rate of 8% per annum. The $2,493,777 is recorded in notes payable related party.

NOTE 5 – CONVERTIBLE NOTES PAYABLE

2004 NOTES

In August and October 2004, the Company completed two tranches of a private offering of Senior Secured Convertible Notes and Warrants.  Gross proceeds from the initial tranche of the offering were $15,000,000.  Gross proceeds from the second tranche of the offering were $5,000,000.  The notes pay interest at the prime rate plus 7.25% per annum, mature two years from the date of issue, are collateralized by substantially all the Company’s assets, and are convertible into 10,695,187 shares of the Company’s common stock based on a conversion price of $1.87 per share.  Monthly principal repayments of $833,333, plus accrued interest commenced on March 1, 2005.  At the Company’s option, and assuming the satisfaction of certain conditions, the Company may pay the monthly installments in cash or through a partial conversion of the notes into shares of the Company’s common stock at a conversion rate equal to the lesser of $1.87 (as may be adjusted to prevent dilution), or 93% of the weighted average trading price of the Company’s common stock on the trading day preceding the conversion.  Note purchasers received warrants to purchase 5,194,806 shares of the Company’s common stock at an exercise price of $1.54 per share, for a period of three years.

On December 1, 2005, the Company and the holders of the 2004 Notes entered into an agreement, that among other things lowered the conversion price of the Notes, granted additional warrants to purchase shares of common stock and lowered the exercise price of existing and newly issued warrants.  In accordance with SFAS 5, Accounting for Contingencies, the Company recorded the effect of this agreement in the financial statements as of November 30, 2005.  In accordance with EITF 96-19, Debtor’s Accounting for a Modification or Exchange of Debt Instruments, the Company recognized this transaction as an extinguishment of the existing debt and the issuance of new debt.  The Company wrote off unamortized discount and deferred financing associated with the original debt in the amount of $773,564, including the amount in interest and financing expense.  In addition, in accordance with EITF 98-5 and EITF 00-27, the Company recognized the fair value of the warrants and the beneficial conversion feature associated with the Notes aggregating $7,375,920 as a discount to the Notes as additional paid in capital.

14

GALAXY ENERGY CORPORATION

(A Development Stage Company)

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

NOTE 5 – CONVERTIBLE NOTES PAYABLE (continued)

2004 NOTES (Continued)

On July 7, 2006, the Company and the holders of its senior secured convertible notes issued in 2004 and 2005 entered into a Waiver and Agreement.  The Company had notified the holders of the 2004 Notes of an Equity Liquidity Test Failure on July 3, 2006, as defined in its agreements with the holders, triggering the holders’ right to make an early repayment election in the aggregate amount of $1,217,929.

In the Waiver and Agreement, the Company and the holders agreed to the following:

·     The waiver of the holders’ right to make an early repayment election as a result of the July 2006 Equity Liquidity Test Failure and any Equity Liquidity Test Failure as of August 1, 2006 and/or September 1, 2006;

·     The deferral of the August 2006 and September 2006 installment payments on the 2004 Notes until October 2, 2006, unless earlier converted by the holders;

·     The Company gave the  holders the right to convert up to $5,000,000 in principal amount of the 2004 Notes, plus related interest, as a “Company Alternative Conversion” under the notes through September 30, 2006, with the amounts converted to be applied first to the August 2006 installment payment, second to the September 2006 installment payment, and then to those installments nearest to the maturity date of the 2004 Notes; and

·    The waiver of the Company’s right to prepay any part of the 2004 or 2005 Notes.

During July, August and September 2006, the holders converted a total of $4,812,249 of principal  and accrued interest into 12,993,939 shares of the Company’s common stock, in accordance with the terms of the Waiver and Agreement.

On November 29, 2006, the Company and the holders of the 2004 Notes entered into a Waiver and Amendment Agreement.  The Company had notified the holders of the 2004 Notes of the fact that a Triggering Event under the terms of the Notes had occurred as of August 31, 2006.  Among other things, this would have enabled the holders of the Notes to require the Company to redeem all or any portion of the outstanding principal amount of the Notes at a price equal to the greater of (i) 125% of such principal plus accrued and unpaid interest and (ii) the product of the current conversion rate in effect under the Notes multiplied by the volume-weighted average price of Galaxy’s common stock.  The holders agreed to waive the Triggering Event in consideration for an amendment to the 2004 Notes that reset the principal amounts of the Notes to 125% of the amounts outstanding as of October 31, 2006.  In accordance with EITF 96-19, Debtor's Accounting for a Modification or Exchange of Debt Instruments”, the Company recognized this transaction as an extinguishment of the existing debt and the issuance of new debt.  The Company wrote off unamortized discount and deferred financing associated with the original debt in the amount of $957,101 including the amount in interest and financing cost.  In addition, in accordance with EITF 98-5 and EITF 00-27 the Company recognized the fair value of the warrants and the beneficial conversion feature associated with the Notes aggregating $663,002 as a discount to the Notes.  During the nine months ended August 31, 2007 the Company recorded amortization of the discount in the amount of $663,002 as interest expense.  In addition, the Company paid in cash the full balance due on the 2004 Notes.

15

GALAXY ENERGY CORPORATION

(A Development Stage Company)

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

NOTE 5 – CONVERTIBLE NOTES PAYABLE (continued)

MARCH 2005 NOTES

In March 2005, the Company completed a private offering of Senior Secured Convertible Notes and Warrants to a group of accredited investors.  Gross proceeds from the offering were $7,695,000.  The notes pay interest at the prime rate plus 6.75% per annum, mature April 30, 2007, are subordinated to Galaxy’s secured debt and existing senior debt, and are convertible into 4,093,085 shares of common stock based on a conversion price of $1.88 per share beginning September 1, 2005.  Note purchasers received warrants to purchase 1,637,235 shares of the Company’s common stock at an exercise price of $1.88 per share, for a period of three years.  Principal and interest on the notes are payable upon maturity.

In connection with the agreement entered into with the Holders of the 2004 notes, as discussed above the terms of the March 2005 Notes were also amended to lower the conversion price and lower the exercise price of existing and newly issued warrants.  In accordance with SFAS 5, Accounting for Contingencies, the Company recorded the effect of this agreement in the financial statements as of November 30, 2005.  In accordance with EITF 96-19, Debtor’s Accounting for a Modification or Exchange of Debt Instruments, the Company recognized this transaction as an extinguishment of the existing debt and the issuance of new debt.  The Company wrote off unamortized discount and deferred financing associated with the original debt in the amount of $1,389,033 including the amount in interest and financing cost.  In addition, in accordance with EITF 98-5 and EITF 00-27 the Company recognized the fair value of the warrants and the beneficial conversion feature associated with the Notes aggregating $2,802,876 as a discount to the Notes and as additional paid in capital.  During the nine months ended August 31, 2007 the Company recorded amortization of the discount in the amount of $1,172,506 as interest expense.

On April 27, 2007 the Company and the Holders of the March 2005 Notes entered into an Waiver and Amendment Agreement, which, among other things, extended the term of the March 2005 notes to the earliest of (A) the date of consummation of the PRB Sale,(B) October 31, 2007, and (C) such date as all amounts due under the Notes have been fully paid.  In addition each of the Holders agreed and confirmed the 2005 Subordinated Notes continue to be subordinate to the senior secured indebtedness. As the PRB Sale was not consummated and the Company is prohibited from paying the March 2005 Notes until the senior secured indebtedness is paid in full (currently scheduled for May 31, 2010), the March 2005 Notes are recorded as non-current obligations on the Company’s August 31, 2007 Balance Sheet.

16

GALAXY ENERGY CORPORATION

(A Development Stage Company)

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

NOTE 5 – CONVERTIBLE NOTES PAYABLE (continued)

MAY 2005 NOTES

In May 2005, the Company completed a private offering of Senior Secured Convertible Notes to a group of accredited investors.  Gross proceeds from the offering were $10,000,000.  The notes are secured by a security interest in all of the assets of the Company and the domestic properties of its subsidiaries.  Such security interest ranks equally with that of the 2004 Notes, and senior to the March 2005 Notes.  The notes pay interest at the prime rate plus 7.25% adjusted and payable quarterly.  They mature May 31, 2010, and are convertible into 5,319,149 shares of common stock at any time, based on a conversion price of $1.88 per share. In addition, the Investors received a perpetual overriding royalty interest (“ORRI”) in Galaxy’s domestic acreage averaging from 1% to 3%, depending upon the nature and location of the property, a right of first refusal with respect to future debt and/or equity financings, and a right to participate in any farm-out financing transactions that do not have operating obligations by the financing party as a material component.  The fair value of the ORRI has been calculated to be the difference between the market price per share at the date of issue ($1.14) and the conversion price ($1.88), times the number of shares into which the notes are convertible (5,319,149) or $3,936,170.  This value has been recorded as a reduction of the Company’s undeveloped oil and gas properties full cost pool and as a discount to the notes.  The discount will be amortized over the five-year term of the notes.

On November 29, 2006, the Company and the holders of the May 2005 Notes entered into a Waiver and Amendment Agreement.  The Company had notified the holders of the May 2005 Notes of the fact that a Triggering Event under the terms of the Notes had occurred as of August 31, 2006.  Among other things, this would have enabled the holders of the Notes to require the Company to redeem all or any portion of the outstanding principal amount of the Notes at a price equal to the greater of (i) 125% of such principal plus accrued and unpaid interest and (ii) the product of the current conversion rate in effect under the Notes multiplied by the volume-weighted average price of Galaxy’s common stock.  The holders agreed to waive the Triggering Event in consideration for an amendment to the May 2005 Notes that reset the principal amounts of the Notes to 125% of the amounts outstanding as of October 31, 2006.  In accordance with EITF 96-19, the Company recognized this transaction as an extinguishment of the existing debt and the issuance of new debt.  The Company wrote off unamortized discount and deferred financing associated with the original debt in the amount of $2,500,000 including the amount in interest and financing cost.   In addition, in accordance with EITF 98-5 and EITF 00-27 the Company recognized the fair value of the warrants and the beneficial conversion feature associated with the Notes aggregating $2,750,577 as a discount to the Notes.  During the nine months ended August 31, 2007 the Company recorded amortization of the discount in the amount of $590,641 as interest expense.

APRIL 2006 DEBENTURES

In April 2006, the Company completed a private offering of Subordinated Convertible Debentures and Warrants to a group of accredited investors.  Gross proceeds from the offering were $4,500,000.  The Debentures pay interest at 15% per annum, have a 30-month maturity which will extend under the terms of the financing until all of the Company’s senior debt has been retired, and are subordinated to Galaxy’s secured debt and existing senior debt.  The Debentures are convertible into 2,884,615 shares of common stock based on a conversion price of $1.56 per share.  Debenture purchasers received warrants to purchase 865,383 shares of the Company’s common stock at an exercise price of $1.60 per share, for a period of five years.  Principal and interest on the Debentures are payable upon maturity.

17

GALAXY ENERGY CORPORATION

(A Development Stage Company)

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

NOTE 5 – CONVERTIBLE NOTES PAYABLE (continued)

APRIL 2006 DEBENTURES (Continued)

The fair value of the warrants was estimated as of the issue date under the Black-Scholes pricing model, with the following assumptions: common stock based on a market price of $1.06 per share, zero dividends, expected volatility of 67.46%, risk free interest rate of 4.875% and expected life of 2.5 years.  The fair value of the warrants of $295,029 resulted in a discount of $395,986 which has been recorded as additional paid in capital and as a discount to the Debentures and is being amortized over the term of the Debentures.  Amortization of the discount of $118,709 is included in interest expense for the nine months ended August 31, 2007.

JUNE 2006 DEBENTURES

In June 2006, the Company completed a private offering of Subordinated Convertible Debentures and Warrants to an accredited investor.  Gross proceeds from the offering were $2,500,000.  The Debentures pay interest at 15% per annum, have a 30-month maturity which will extend under the terms of the financing until all of the Company’s senior debt has been retired, and are subordinated to Galaxy’s secured debt and existing senior debt.  The Debentures are convertible into 1,602,564 shares of common stock based on a conversion price of $1.56 per share.  The Debenture purchaser received warrants to purchase 480,769 shares of the Company’s common stock at an exercise price of $1.60 per share, for a period of five years.  Principal and interest on the Debentures are payable upon maturity.

The fair value of the warrants was estimated as of the issue date under the Black-Scholes pricing model, with the following assumptions: common stock based on a market price of $0.79 per share, zero dividends, expected volatility of 67.36%, risk free interest rate of 5.125% and expected life of 2.5 years.  The fair value of the warrants of $92,695 resulted in a discount of $170,555 which has been recorded as additional paid in capital and as a discount to the Debentures and is being amortized over the term of the Debentures.  Amortization of the discount of $51,129 is included in interest expense for the nine months ended August 31, 2007.

The Company has evaluated the embedded conversion feature in the 2004, the March 2005, and the May 2005 Notes, and the April 2006 and the June 2006 Debentures and concluded the feature does not require classification as a derivative instrument because the feature would be classified as equity if it were a freestanding instrument and therefore, meets the scope exception found in SFAS 133, Accounting for Derivative Instruments and Hedging Activities (“SFAS 133”).  Included in the evaluation is the conclusion the Notes and Debentures meet the definition of “conventional convertible instrument” and therefore the embedded conversion feature is not subject to the provisions of EITF 00-19.  Further the Company has evaluated the detachable warrants related to the 2004 and the March 2005 Notes and the April 2006 and the June 2006 Debentures, and concluded that the warrants also meet the scope exception found in SFAS 133 and are appropriately classified as equity.  The Company has also evaluated the freestanding registration rights agreements attached to the Notes and Debentures and have concluded they do meet the definition of derivative instruments under SFAS 133.  The fair value of the derivative liabilities has been determined not to be significant based on a probability- weighted, discounted cash flow evaluation of its terms.

18

GALAXY ENERGY CORPORATION

(A Development Stage Company)

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

NOTE 5 - CONVERTIBLE NOTES PAYABLE (continued)

At August 31, 2007 and November 30, 2006 convertible notes consist of the following:

	2007			2006
2004 Notes	$	-		$	4,160,505
Less unamortized discount		-			(663,002	)
March 2005 Notes		7,695,000			7,695,000
Less unamortized discount		-			(1,172,506	)
May 2005 Notes		12,500,000			12,500,000
Less unamortized discount		(2,159,936	)		(2,750,577	)
April 2006 Notes		4,500,000			4,500,000
Less unamortized discount		(181,963	)		(300,671	)
June 2006 Notes		2,500,000			2,500,000
Less unamortized discount		(88,823	)		(139,951	)
		24,764,278			26,328,798
Less current portion, net		-			(10,019,996	)
long term portion, net	$	24,764,278		$	16,308,802

Total unamortized discount on all Notes and Debentures at August 31, 2007 in the amount of $2,430,722 will be amortized and recognized as interest expense over the remaining terms of the respective debt instruments.

Total principal payments scheduled to be made in the next twelve months, including related party debt, are $23,863,505; however, under the terms of the Senior Secured Debt, the Company is prohibited from making $16,168,505 of such principal payments until the senior indebtedness has been paid. The Senior Secured Debt is scheduled for repayment on May 31, 2010; however, the Company currently plans to utilize the proceeds from any future sale of the Company’s oil and gas properties to repay or reduce those amounts.

NOTE 6 – STOCKHOLDERS’ EQUITY

During the nine months ended August 31, 2007, the Company issued 2,000,000 shares of its common stock to its senior secured creditors in exchange for the creditors’ consent to the Powder River Basin Asset Sale.  The creditors’ consent was required because they have a security interest covering the assets to be sold.  The Company issued the shares at the closing market price per share on the dates of issuance, and the value associated with these shares, $410,000 was included in deferred selling costs.  Since the purchase and sale agreement expired on August 31, 2007 and was not extended, the $410,000 was charged to interest expense at August 31, 2007.

19

GALAXY ENERGY CORPORATION

(A Development Stage Company)

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

NOTE 7 – STOCK OPTION PLAN

The Company adopted the 2003 Stock Option Plan (the “Plan”), as amended.  Under the Plan, stock options may be granted at an exercise price not less than the fair market value of the Company’s common stock at the date of grant.  Options may be granted to key employees and other persons who contribute to the success of the Company.  The Company has reserved 6,500,000 shares of common stock for the plan. At August 31, 2007, and November 30, 2006, options to purchase 1,545,000 and 1,785,000 shares, respectively, were available to be granted pursuant to the stock option plan.

On January 2, 2007, the Company granted each of the Company’s outside directors options to purchase 60,000 shares of the Company’s common stock for a term 10 years at the closing price of the common stock on the date of grant.  The options were vested upon grant.

NOTE 8 – SUBSEQUENT EVENTS

Subsequent to August 31, 2007 and through the date of the filing of this report, the Company has borrowed an additional $975,000 from the Bruner Trust, under the same terms and conditions as the other notes.

On August 30, 2007, the Company submitted a revised plan of action, which took the termination of the PSA with PetroHunter into account, to bring the Company into compliance with AMEX’s continued listing standards.  On October 15, 2007 AMEX notified the Company that AMEX accepted such revised plan based on the expectation that the Company will complete a sale of certain assets and utilize the proceeds to pay down   a significant portion of its outstanding debt, and continued the Company’s listing pursuant to an extension until December 31, 2007.  The Company will be subject to periodic review by AMEX staff during the extension period.

20

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

Overview and Plan of Operation

We spent fiscal years 2003, 2004, 2005 and 2006 obtaining oil and gas properties in the Piceance Basin of Colorado and the Powder River Basin of Wyoming and Montana and obtaining the funding to pay for those properties, commence drilling operations and complete the infrastructure necessary to deliver natural gas to nearby pipelines.  Most of this funding has been high-interest debt financing.

As of October 5, 2007, we had interests in 176 completed wells (26 of which were delivering natural gas into sales pipelines), 61 wells in various stages of completion and 8 water disposal wells.  We recorded our first revenues from natural gas sales during the fiscal year ended November 30, 2004 and we currently are producing about 365 thousand cubic feet per day.  If we are successful in completing the sale of a portion of our Powder River Basin assets as discussed below, the well count will be reduced.  We will require additional capital to continue to dewater wells in the Powder River Basin and to complete and commence production from any remaining existing uncompleted wells and to drill additional wells in both the Powder River and Piceance Basins.  If we are successful in securing the necessary funding and in completing the existing wells and adding additional wells, we anticipate an increase in production of natural gas and sales revenues during future fiscal years; however, until such natural gas production and sales revenues increase sufficiently these revenues will not cover all of our ongoing exploration and development operations, debt repayments and other commitments.

At August 31, 2007, our working capital deficit was approximately$4,000,000 and a stockholders’ deficit of approximately $5,320,000.  As of that date we had contractual obligations due within twelve months totaling approximately $30,000,000, as explained more fully below. To settle such debt, the Company is exploring the sale of a portion of its oil and gas properties.  If a sale is completed, we will first pay down or pay off all of our senior debt and then we will negotiate to convert all or substantially all of our convertible debt into common stock of the Company.  We believe that we would then be able to continue to pursue funding and industry participation alternatives to ensure our ability to continue to acquire additional acreage and complete additional drilling activity on any remaining acreage.

If we cannot find a buyer and suitable terms for a sale, or additional debt or equity placements, we may be forced to seek the protection of the bankruptcy laws.  Furthermore to close a sale, we may be required to reduce the sale price of an asset sale, which could result in a significant impairment (and loss to the Company) to the carrying value of the oil and gas properties.

Going Concern

The report of our independent registered public accounting firm on the financial statements for the year ended November 30, 2006, includes an explanatory paragraph indicating substantial doubt as to our ability to continue as a going concern.  We have incurred a cumulative net loss of approximately $78,000,000 for the period from inception to August 31, 2007.  We will require significant monies to sustain our operations and satisfy our contractual obligations for our planned oil and gas exploration and development operations.  Our ability to establish the Company as a going concern is dependent upon our ability to obtain additional financing or proceeds from the sale of assets, in order to fund our planned operations and ultimately, to achieve profitable operations.

21

Results of Operations

Three months ended August 31, 2007 compared to the three months ended August 31, 2006

During the three months ended August 31, 2007, revenues from natural gas sales decreased to $76,303 from $281,559 the year before.  A total of 16 wells produced and sold approximately 45,000 Mcf of natural gas in 2007, compared to 38 wells that sold 51,719 Mcf in 2006.  The 2007 production decrease reflects the shutting in of the uneconomic Glasgow field in the Powder River Basin and mechanical problems encountered on 4 wells in the West Recluse Field.  Average prices received for gas sold has decreased, $2.68 in 2007 compared to $4.38 in 2006, due to the pipeline line constraints out of the Rocky Mountain region.  Lease operating expense increased significantly to $445,000 as the Company discontinued the capitalization of certain dewatering costs ($346,000 for the quarter ended August 31, 2007) compared to $106,510 the year before.

For the three months ended August 31, 2007 and 2006, we incurred general and administrative expenses of $761,617 and $1,172,301, respectively, as summarized below:

	2007		2006
Stock based compensation	$	289,589	$	315,407
Salaries and benefits		212,595		233,717
Professional and consulting fees		12,245		42,869
Investor relations		108,593		238,783
Legal		41,555		112,373
Travel and entertainment		10,864		34,690
Office lease and expenses		39,575		61,557
Audit and accounting		15,990		31,166
Directors fees, insurance, prospect generation & other		30,611		101,739
Total	$	761,617	$	1,172,301

Significant period-to-period variances include:

·     Lower stock based compensation expense in 2007 versus 2006 is due to the Company granting fewer options than in prior years and certain of the previous grants being fully expensed in prior periods.

·     Professional and consulting fees decrease reflects the termination of our consulting geologist which had been employed by the Company in 2006, resulting in savings of $24,000; and as a result of our concerted effort to control such costs.

·     Investor relations expenses in 2006 included the costs associated with a special shareholders meeting to approve the issuance of additional shares of common stock.  No such special meeting was held in 2007, resulting in savings of approximately $40,000.  In 2006 we incurred expenses for the preparation and distribution of our annual report to shareholders of approximately $50,000. We have not prepared an annual report to shareholders for 2007.

·     Travel and entertainment costs reflect a significant decrease in 2007 compared to 2006 as a result of our concerted effort to control such costs, together with the significantly decreased level of operational activity in 2007.

·     Decreased audit and accounting fees in 2007 primarily reflects the reduction of outside accounting services as compared to 2006 when our level of operations was significantly greater.

As a result of lower natural gas prices at August 31, 2007 we recorded an impairment expense of $2,370,880 for the three months then ended, representing the excess of capitalized costs over the ceiling as

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calculated in accordance with the full cost rules.  Impairment expense of $1,031,160 was recorded for the three months ended August 31, 2006.

Depreciation, depletion and amortization expense (“DD&A”) of $232,056 in 2007 reflects a decrease from the 2006 amount of $318,379.  The decrease reflects lower DD&A on oil and gas properties of $19,837 or $.44/Mcf in 2007 compared to $177,363 or $3.13/Mcf in 2006.  The lower DD&A reflects a lower amortization base following the impairment write-down of $1,031,160 in 2006 and the impairment expense recognized in the first six months of this fiscal year.

Interest and financing costs decreased to $2,044,630in 2007 from $3,970,113 in 2006, reflecting significantly lower amortization of discount on the 2004 Notes, partially offset by the higher debt levels in 2007.  The table below summarizes interest and financing costs for the three months ended August 31, 2007 and 2006.

	2007		2006
Interest on outstanding debt	$	1,044,969	$	1,324,744
Interest on outstanding debt, related party		284,682		-
Amortization of discount		303,184		2,251,447
Amortization of deferred finance costs		411,795		47,839
Discount on shares issued upon conversion of principal and interest at below market rates		-		346,083
Total	$	2,044,630	$	3,970,113

Significant year-to-year variances include:

·     Interest on outstanding debt, related party in 2007 reflects costs associated with borrowing from the Bruner Family Trust in late 2006 and 2007.  No such borrowings existed in the period ended August 31, 2006.

·     Lower amortization of discount in 2007 reflects the lower balance of debt on the 2004 Notes in 2007 compared to 2006.   As a result of the principal repayment schedule of the 2004 Notes, higher amortization of discount is recorded when debt levels are higher.  As we have paid the 2004 Notes down from $12,500,000 in 2006 to $0 in 2007, related amortization of discount is significantly less in 2007.

Nine months ended August 31, 2007 compared to the nine months ended August  31, 2006

During the nine months ended August 31, 2007 we recorded natural gas sales volumes of 118,000 mcf compared to 161,501 mcf in the same period in 2006.   We recorded natural gas sales revenues of $447,232 ($3.79/mcf) and lease operating and production tax expense of $704,151 ($5.97/mcf) for the nine months ending August 2007 compared to natural gas sales revenues of $955,895 ($5.92/mcf) and $590,311 ($3.66/mcf) of lease operating and production tax expense during the same period in 2006.  Depreciation, depletion and amortization (“DD&A”) expenses associated with the gas sales were $180,645 ($1.53/mcf) during the nine months ended August 31, 2007, compared with $523,263 ($3.24/mcf) of DD&A expenses during the same period of 2006.

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For the nine-month periods ended August 31, 2007 and 2006, we recorded general and administrative costs of $2,801,617 and $3,652,158, respectively, as summarized below.

	Nine months ended August 31,
	2007		2006
Stock Based compensation	$	891,647	$	999,660
Salaries and benefits		648,589		714,912
Professional and consulting		51,412		189,182
Investor relations		331,864		659,103
Legal		267,172		290,092
Travel & entertainment		46,049		97,769
Office lease and expenses		144,386		173,234
Audit and accounting		167,439		227,580
Director fees		133,700		165,774
Insurance, prospect generation and other		119,359		134,852
	$	2,801,617	$	3,652,158

Significant period-to-period variances include:

·     Lower stock based compensation expense in 2007 versus 2006 is due to the Company granting fewer options than in prior years and certain of the previous grants being fully expensed in prior periods.

·     Professional and consulting fees decrease in 2007 reflects the termination of our consulting geologist which we had employed in 2006, resulting in savings of $24,000; reduced fees paid to independent reservoir engineer for the 2007 reserve report, resulting in savings of $20,000, the termination of the consulting agreement with our Founder, resulting in savings of $30,000, and savings associated with the fact we did not require the preparation of a market valuation report in 2007, having completed one in 2006, resulting in savings of $30,000.

·     Investor relations expenses in 2006 included the costs associated with a special shareholders meeting to approve the issuance of additional shares of common stock, resulting in savings of approximately $40,000.  In 2006 we incurred expenses for the preparation and distribution of our annual report to shareholders of approximately $50,000.  We have not prepared an annual report to shareholders for 2007. In addition, we terminated the contract with one investor relations firm subsequent to August 31, 2006, resulting in savings of $43,000 in 2007.

·     Increased legal fees in 2007 reflects legal fees incurred to prepare and file numerous 8-K reports and file preliminary proxy statements with the SEC; approximately $20,000 and in house legal fees incurred in negotiations for the sale of certain oil and gas assets; approximately $40,000.

·     Travel and entertainment costs reflect a significant decrease in 2007 compared to 2006 as a result of our concerted effort to control such costs, together with the significantly decreased level of operational activity in 2007.

·     Decreased audit and accounting fees in 2007 primarily reflects the reduction of outside accounting services as compared to 2006 when our level of operations was significantly greater.

As a result of lower natural gas prices at August 31, 2007 we recorded an impairment expense of $3,866,195 for the nine months then ended, representing the excess of capitalized costs over the ceiling as calculated in accordance with the full cost rules.  Impairment expense of $1,031,160 was recognized in 2006.

Depreciation, depletion and amortization expense (“DD&A”) of $511,168 in 2007 reflects a decrease from the 2006 amount of $680,707.  The decrease reflects lower DD&A on oil and gas

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production as discussed above.  The lower DD&A reflects a lower amortization base following the impairment write-down of $1,031,160 in 2006. Lower DD&A on oil and gas production was partially offset by higher depreciation of ARO assets, and higher accretion of ARO of $82,453 in 2007 compared to $3,493 in 2006.

We recorded interest and financing costs of $7,119,791 in the nine months ending August 31, 2007 compared to $12,918,109 in the previous year’s period.  The table below summarizes interest and financing costs for the nine months ended August 31:

	2007		2006
Interest on outstanding debt	$	3,282,157	$	3,647,299
Interest on outstanding debt – related party		687,714		-
Amortization of discount		2,738,125		8,586,741
Amortization of deferred finance costs		411,795		262,986
Discount on shares issued upon conversion of principal and interest at below market rates				346,083
Fees paid to extend note		-		75,000
Total	$	7,119,791	$	12,918,109

Significant year-to-year variances include:

·     Interest on outstanding debt, related party in 2007 reflects costs associated with borrowing from the Bruner Family Trust in late 2006 and 2007.  No such borrowings existed in the period ended August 31, 2006.

·     Lower amortization of discount in 2007 reflects the lower balance of debt on the 2004 Notes in 2007 compared to 2006.  As a result of the principal repayment schedule of the 2004 Notes, higher amortization of discount is recorded when debt levels are higher.  As we have paid the 2004 Notes down from $12,500,000 in 2006 to $-0- in 2007, related amortization of discount is significantly less in 2007.

·     Lower amortization of deferred finance costs reflects the write off of unamortized balances of such costs when the related debt was extinguished and reissued on November 30, 2005.

Liquidity and Capital Resources

Operating Activities.  For the nine months ended August 31, 2007 we used $3,131,964 for operating activities, as compared to $3,292,487 for the same period in 2006.  Significant adjustments to reconcile the net loss of $14,541,647 to net cash used by operating activities for 2007 were $2,738,126 for amortization of discount and deferred financing costs on convertible debt, $891,647 of stock based compensation expense, $3,866,195 of impairment of oil and gas properties and DD&A of $511,168.  In contrast, the equivalent adjustments for 2006 to the net loss of $17,903,962 included $8,849,726 for amortization of discount and deferred financing costs on convertible debt, $999,660 of stock based compensation expense, $1,031,160 impairment of oil and gas properties and $680,707 of DD&A.

Investing Activities.  Our investing activities used net cash of $1,882,318 after recoveries, in the nine months ended August 31, 2007, as compared to $1,391,441 of cash used for the comparable period of 2006.  The increase is due to an earnest money deposit and reimbursement of operating costs we received of $2,216,882, on the proposed sale of our Powder River Basin assets in the 2007 period that was not completed.

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Financing Activities.  Since inception, we have funded our operating and investing activities through the sale of our debt and equity securities, raising net proceeds of $75,179,037 through the period ended August 31, 2007.  Financing activities raised cash of $4,458,272 in the first nine months of fiscal 2007, as compared to $3,522,058 in 2006.

From December 2002 through May 2003, we sold 1,602,000 shares of common stock for gross proceeds of $1,602,000.  In October 2003, we completed a $5,640,000 private placement of 7% secured convertible debentures and warrants, due two years from date of issue and secured by substantially all of our assets.  Debentures purchasers received five-year warrants to purchase 2,867,797 shares of common stock at an exercise price of $0.71 per share and 2,867,797 shares of common stock at an exercise price of $0.83 per share.  We filed a registration statement covering the shares underlying the debentures and warrants, but did not meet the deadline associated with this filing obligation.  We paid a penalty of $404,000 to the holders of the debentures.  During the year ended November 30, 2004, all of the debentures were converted at $0.59 per share into 9,559,322 shares of common stock.

In December 2003, we completed a private placement of 2,503,571 shares of our common stock and warrants to purchase 500,715 common shares, resulting in gross proceeds of $3,505,000.  The warrants were exercisable for a four-year period at an original price of $2.71 per share.  In accordance with the antidilutive rights provisions, the exercise prices of those warrants with original exercise prices in excess of $1.54 were reset to $1.54 per share, in connection with the issuance of the 2004 notes.  We granted registration rights to the purchasers in this private placement.

We completed a second private placement of 6,637,671 shares of our common stock and warrants to purchase 1,327,535 common shares in January 2004, resulting in gross proceeds of $11,947,800.  The warrants were exercisable for a five-year period at an original price of $4.05 per share.  In accordance with the antidilutive rights provisions, the exercise prices of those warrants with original exercise prices in excess of $1.54 were reset to $1.54 per share, in connection with the issuance of the 2004 Notes.  We granted registration rights to the purchasers in this private placement as well.

In August and October 2004, we completed two tranches of a private placement of senior secured convertible notes (the “2004 Notes”) and warrants (the “2004 Warrants”).  Gross proceeds from the initial tranche were $15,000,000, while gross proceeds from the second tranche were $5,000,000.  The 2004 Notes paid interest at the prime rate plus 7.25% per annum, originally matured two years from the date of issue, were collateralized by substantially all of our assets, and were originally convertible into 10,695,187 shares of our common stock based on a conversion price of $1.87 per share.  In January 2005, under the terms of the 2004 Notes, we were required to pay accumulated interest to that date.  Commencing on March 1, 2005, we were required to make monthly payments of principal in the amount of $833,333 plus accrued interest.  For the year ended November 30, 2005, we made total payments on the 2004 Notes of $10,152,666 consisting of $7,500,000 in principal repayments and $2,652,666 of interest.  Of that amount we paid $8,337,748, or 82% of the total payment, using shares of common stock.  Note purchasers received the three-year, 2004 Warrants, which originally allowed the holders to purchase 5,194,806 shares of common stock at $1.54 per share.

On March 1, 2005, we completed a private placement of $7,695,000 in senior subordinated convertible notes (the “March 2005 Notes”) to a group of accredited investors to fund our entry into our Piceance Basin project.  The March 2005 Notes were originally payable on April 30, 2007 (but were subordinated in payment to the 2004 Notes), accrue interest at the prime rate plus 6.75% per annum, adjusted quarterly and payable at maturity, and were originally convertible into 4,093,086 shares of our common stock based on a conversion price of $1.88 per share.  March 2005 Note purchasers received

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three-year warrants (the “2005 Warrants”), which originally allowed the holders to purchase 1,637,234 shares of common stock at $1.88 per share.

On May 31, 2005, we completed a private offering of senior secured convertible notes to essentially the same group of accredited investors that purchased our 2004 Notes and Warrants (the “May 2005 Notes”).  Gross proceeds from the offering were $10,000,000.  The May 2005 Notes are secured by a security interest in all of our assets and the domestic properties of our subsidiaries.  Such security interest ranks equally with that of the 2004 Notes, and senior to the March 2005 Notes.  The May 2005 Notes mature and are payable on May 31, 2010 (but can be redeemed by the holders after May 31, 2008) and bear interest at the prime rate plus 7.25%, adjusted and payable quarterly.  The May 2005 Notes were originally convertible into 5,319,149 shares of our common stock based on a conversion price of $1.88 per share.  In addition, the Investors received a perpetual overriding royalty interest in our domestic acreage averaging from 1% to 3%, depending upon the nature and location of the property, a right of first refusal with respect to future debt and/or equity financings, and a right to participate in any farm-out financing transactions that do not have operating obligations by the financing party as a material component.

On December 1, 2005, we entered into a Waiver and Amendment Agreement (the “2005 Waiver and Amendment”) with the holders of the 2004 Notes and the holders of the 2005 Notes.  Under the agreement, we and the holders waived all claims in connection with Dolphin Energy Corporation, our wholly-owned subsidiary, having entered into a Third Amendment to Participation Agreement with our partner in our Piceance Basin project, Exxel Energy Corporation as of October 4, 2005.  The Third Amendment set the working interest between us and Exxel at 25%/75%, consistent with the original intent of the parties.  As such, the Third Amendment clarified that Exxel was obligated to pay the next $14 million in project costs to bring its payments to 75% of the total costs, thereby adjusting for us having paid about 50% of the land cost to get the project started.

In addition, the 2005 Waiver and Amendment, among other things, effected the following changes:

·     Lowered the conversion price to $1.25 for conversions by the holders of the 2004 Notes, the May 2005 Notes, and the March 2005 Notes;

·     Lowered the exercise price of the 2004 Warrants and the 2005 Warrants to $1.25 per share and increased the aggregate number of shares purchasable under the 2004 Warrants from 5,194,806 to 6,400,002;

·     Caused the exercise price of warrants issued in December 2003 and January 2004 being lowered to $1.25 under the anti-dilution provisions of such warrants;

·     Deferred monthly installment payments on the 2004 Notes until April 1, 2006;

·     Extended the maturity date of the 2004 Notes to July 1, 2007; and

·     Extended any redemption or conversion of the 2004 Notes by Galaxy until June 22, 2006.

On April 25, 2006, we entered into a Securities Purchase Agreement with several accredited investors pursuant to which the investors purchased in the aggregate, $4,500,000 principal amount of Subordinated Convertible Debentures.  In addition, the investors also received three-year warrants that allow the holders to purchase 865,383 shares of common stock at $1.60 per share.  The debentures are convertible at any time by the holders into shares of our common stock at a price equal to $1.56; are subordinated to all of our senior debt; pay interest at 15% per annum, payable at maturity; and have a term of 30 months, which will extend automatically until all of our senior debt has been retired.  Additionally, in the event the debentures are retired at maturity, the holders are entitled to an additional payment equal to the sum of 25% plus 0.75% for each month (or part thereof) in excess of 30 months that the debentures have remained outstanding.

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On June 20, 2006, we entered into a Securities Purchase Agreement with an accredited investor pursuant to which the investor purchased $2,500,000 principal amount of Subordinated Convertible Debentures on the same terms and conditions set forth in the previous paragraph.

During the year ended November 30, 2006, we issued four separate subordinated unsecured promissory notes for a total of $5,500,000 in favor of Bruner Family Trust UTD March 28, 2005 (the “Bruner Family Trust”), a related party.  One of the trustees of the Bruner Family Trust is Marc E. Bruner, the president and a director of the company.  Interest accrues at the rate of 8% per annum and the note matures at the later of 120 days from issue or the time at which our senior indebtedness has been paid in full.

On November 29, 2006, we entered into a Waiver and Amendment Agreement (the “2006 Waiver and Amendment”) with the holders of the 2004 Notes and the 2005 Notes.  We had earlier notified the holders of the 2004 Notes and May 2005 Notes of the fact that our accounts payable had exceeded the permitted $2,500,000 ceiling set forth in the 2004 Notes and May 2005 Notes, thereby resulting in a Triggering Event under the terms of those Notes.  Among other things, this would have enabled the holders of the Notes to require us to redeem all or any portion of the outstanding principal amount of the Notes at a price equal to the greater of (i) 125% of such principal plus accrued and unpaid interest and (ii) the product of the current conversion rate in effect under the Notes multiplied by the volume-weighted average price of our common stock.  The holders agreed to waive the Triggering Event in consideration for an amendment to the 2004 Notes and May 2005 Notes that reset the principal amounts of the Notes to 125% of the amounts outstanding as of October 31, 2006.  We and the holders also agreed to waive any future Triggering Event that might result from our accounts payable exceeding $2,500,000. However, if our accounts payable should exceed $5,000,000, it would result in an immediate breach of the Notes.  We and the holders agreed to other amendments with respect to the 2004 Notes and May 2005 Notes and warrants previously issued by us to the holders.

We also obtained the consent of the holders of the 2004 Notes and May 2005 Notes to the proposed sale of our Powder River Basin assets (the “PRB Sale”) to PetroHunter as described above.  Such consent was required as the holders have a security interest covering these assets.  The note holders conditioned their consent on the following:  completion of the PRB Sale by February 28, 2007 and our compliance with the Waiver and Amendment Agreement and all of our obligations under the various agreements with the note holders.  Further, were required to (i) pay the 2004 Notes and May 2005 Notes in full, (ii) deliver to the holders 1,000,000 of the PetroHunter shares to be received by us as part of the PRB Sale consideration and 10,000,000 shares of our common stock and (iii) retire all of our outstanding subordinated convertible debt using the consideration we received in the PRB Sale.  Additionally, the holders and PetroHunter were required to enter into a suitable registration rights agreement with respect to the 1,000,000 PetroHunter shares.  The purchase and sale agreement expired on August 31, 2007 and was not extended. The Company is currently searching for other buyers and suitable terms for a sale of some of its assets

Because the PRB Sale was not consummated by January 31, 2007, we issued 2,000,000 additional shares of our common stock to the holders of the 2004 Notes and the May 2005 Notes in order to maintain their consent to the PRB Sale, as required under the 2006 Waiver and Amendment.  We have agreed to register these shares.

In October 2006, Bruner Trust, a related party, acquired a promissory note we had issued to DAR, LLC in the original principal amount of $2,600,000.  While the note, as amended, had a stated maturity date of December 1, 2006, Bruner Trust has stated that it will not enforce its rights under the note until November 30, 2007.

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In April 2007, we entered into a Waiver and Amendment Agreement with the holders of the March 2005 Notes, which, among other things, extended the term of the March 2005 Notes to the earliest of (A) the date of consummation of the PRB Sale, (B) October 31, 2007, and (C) such date as all amounts due under the Notes have been fully paid.  We are seeking an extension of the October 31, 2007 date to February 29, 2008.

During the nine months ended August 31, 2007, we issued nine separate subordinated unsecured promissory notes for a total of $6,125,000 in favor of the Bruner Family Trust a related party.  Interest accrues at the rate of 8% per annum and the note matures at the later of 120 days from issue or the time at which our senior indebtedness has been paid in full.

Schedule of Contractual Obligations

The following table summarizes our obligations and commitments to make future payments under our notes payable, operating leases, employment contracts and consulting agreement for the periods specified as of August 31, 2007.

Contractual obligations (1)	Payments due by period
	Total	Less than 1 year	1-3 years	3-5 years	More than 5 years
Convertible Notes Payable Senior Secured Notes Payable  (2)     Principal     Interest Senior Subordinated Notes Payable  (3)     Principal     Interest Notes payable, related party     Principal    Interest    Principal    Interest	$12,500,000 5,324,144 14,695,000 5,543,555 14,118,777 632,215 2,049,728 484,672	$                 - 1,942,808 7,695,000 (4) 2,916,089 (4) 14,118,777 (4) 632,215 (4)                       2,049,728                          484,672	$12,500,000 3,381,336 7,000,000 2,627,466 - -	$              - - - - - -	$    - - - - - -
Office, Equipment Leases & Other	333,702	122,051	211,652	-	-
TOTAL	$55,681,793	$29,961,340	$25,720,454	$             -	$     -

(1) This table excludes the costs of drilling obligations in our European permits, as we reached agreement with third parties to fund our share of the obligation amount, should such amount be spent.  In the event we do not fulfill those drilling obligations, we will forfeit the permit.  We have excluded asset retirement obligations because we are not able to precisely predict the timing for these amounts.

(2) Under certain conditions, as described elsewhere in this report, we have the option to pay the principal and interest with shares of common stock instead of cash.  Interest payments were calculated using actual interest rates charged through August 31, 2007, and 15.5% thereafter.

(3) Under certain conditions, as described elsewhere in this report, we have the option to pay the principal and interest with shares of common stock instead of cash.  Interest payments were calculated using actual interest rates charged through August 31, 2007, and 15% thereafter.

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(4) The due dates of these Notes fall within the period specified above; however, we are prohibited for repaying these Notes until the senior secured indebtedness has been satisfied.  These notes have been classified as non-current obligations as of August 31, 2007.

Critical Accounting Policies and Estimates

Our discussion and analysis of our financial condition and results of operations are based upon our condensed consolidated financial statements, which have been prepared in accordance with accounting principles generally accepted in the United States of America.  The preparation of these financial statements requires us to make estimates and judgments that affect the reported amounts of assets, liabilities, revenues and expenses, and related disclosures of contingent assets and liabilities.  On an ongoing basis, we evaluate our estimates, including those related to impairment of long-lived assets.  We base our estimates on historical experience and on various other assumptions that we believe to be reasonable under the circumstances, the results of which form the basis for making judgments about the carrying value of assets and liabilities that are not readily apparent from other sources.  Actual results may differ from these estimates under different assumptions or conditions; however, we believe that our estimates, including those for the above-described items, are reasonable.

Oil and Gas Properties.  We follow the full cost method of accounting for oil and gas operations.  Under this method, all costs related to the exploration for and development of oil and gas reserves are capitalized on a country-by-country basis.  Costs include lease acquisition costs, geological and geophysical expenses, overhead directly related to exploration and development activities and costs of drilling both productive and non-productive wells.  Proceeds from the sale of properties are applied against capitalized costs, without any gain or loss being recognized, unless such a sale would significantly alter the rate of depletion and depreciation.

We calculate depreciation and depletion of our oil and gas using the unit-of-production method based upon estimated proven oil and gas reserves.  The costs of significant unevaluated properties are excluded from costs subject to depletion.  For depletion and depreciation purposes, relative volumes of oil and gas production and reserves are converted at the equivalent conversion based upon relative energy content.

In applying the full cost method, we perform a ceiling test whereby the carrying value of oil and gas properties and production equipment, net of recorded future income taxes and the accumulated provision for site restoration and abandonment costs, is compared annually to an estimate of future net cash flow from the production of proven reserves.  Costs related to undeveloped oil and gas properties are excluded from the ceiling tests.  Discounted net cash flow, utilizing a 10% discount rate, is estimated using year end prices, less estimated future general and administrative expenses, financing costs and income taxes.  If such capitalized costs exceed the ceiling, we will record a write-down to the extent of such excess as a non-cash charge to earnings.  Any such write-down will reduce earnings in the period of occurrence and result in lower depreciation and depletion in future periods.  A write-down may not be reversed in

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future periods, even though higher oil and natural gas prices may subsequently increase the ceiling. As a result of lower natural gas prices at August 31, 2007 and May 31, 2007, we recorded an impairment expense of $3,866,195 for the nine months then ended, representing the excess of capitalized costs over the ceiling at that date. We recorded a ceiling write down during the year ended November 30, 2006 in the amount of $1,328,432 representing the excess of capitalized costs over the ceiling amount.

We intend to sell a portion of our oil and gas properties.  Full cost accounting rules do not include provisions for segregating those assets and identifying them as held for sale.  Accordingly, those assets are reflected on the balance sheet as either evaluated or unevaluated oil and gas properties, as appropriate.

Oil and Gas Reserves.  The determination of depreciation and depletion expense as well as ceiling test write-downs related to the recorded value of our oil and natural gas properties are highly dependent on the estimates of the proved oil and natural gas reserves.  Oil and natural gas reserves include proved reserves that represent estimated quantities of crude oil and natural gas which geological and engineering data demonstrate with reasonable certainty to be recoverable in future years from known reservoirs under existing economic and operating conditions.  There are numerous uncertainties inherent in estimating oil and natural gas reserves and their values, including many factors beyond our control.  Accordingly, reserve estimates are often different from the quantities of oil and natural gas ultimately recovered and the corresponding lifting costs associated with the recovery of these reserves.  Price changes will affect the economic lives of oil and gas properties and, therefore, price changes may cause reserve revisions.  We are not aware of any material adverse issues related to our reserves regarding regulatory approval, the availability of additional development capital, or the installation of additional infrastructure.

Asset Retirement Obligations.  SFAS No. 143, Accounting for Asset Retirement Obligations requires that we estimate the future cost of asset retirement obligations, discount that cost to its present value, and record a corresponding asset and liability in our consolidated balance sheets.  The values ultimately derived are based on many significant estimates, including future abandonment costs, inflation, market risk premiums, useful life, and cost of capital.  The nature of these estimates requires us to make judgments based on historical experience and future expectations.  Revisions to the estimates may be required based on such things as changes to cost estimates or the timing of future cash outlays.  Any such changes that result in upward or downward revisions in the estimated obligation will result in an adjustment to the related capitalized asset and corresponding liability on a prospective basis.

Revenue Recognition.  We derive our revenue primarily from the sale of produced natural gas and crude oil.  We report revenue gross for the amounts received before taking into account production taxes and transportation costs which are reported as separate expenses.  Revenue is recorded in the month production is delivered to the purchaser at which time title changes hands.  We make estimates of the amount of production delivered to purchasers and the prices we will receive.  We use our knowledge of our properties; their historical performance; the anticipated effect of weather conditions during the month of production; NYMEX and local spot market prices; and other factors as the basis for these estimates.  Variances between estimates and the actual amounts received are recorded when payment is received.  A majority of our sales are made under contractual arrangements with terms that are considered to be usual and customary in the oil and gas industry.

Impairment of long-lived assets.  Our long-lived assets include property and equipment.  We assess impairment of long-lived assets whenever changes or events indicate that the carrying value may not be recoverable.  In performing our assessment we must make assumptions regarding estimated future cash flows and other factors to determine the fair value of the respective assets.  If these estimates change in the future we may be required to record impairment charges against these respective assets.

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Stock based compensation.  On December 1, 2005, we adopted FAS No. 123(R), “Accounting for Stock-Based Compensation,” using the modified prospective method, which results in the provisions of FAS 123(R) being applied to the consolidated financial statements on a going-forward basis.  Prior periods have not been restated.  FAS 123(R) requires companies to recognize share-based payments to employees as compensation expense on a fair value method.  Under the fair value recognition provisions of FAS 123(R), stock-based compensation cost is measured at the grant date based on the fair value of the award and is recognized as expense over the service period, which generally represents the vesting period.  The expense recognized over the service period is required to include an estimate of the awards that will be forfeited.  Previously, no such forfeitures have occurred.  We are assuming no forfeitures going forward based on our historical forfeiture experience.  The fair value of stock options is calculated using the Black-Scholes option-pricing model

Forward-Looking Statements

This report includes “forward-looking statements.”  All statements other than statements of historical facts included or incorporated by reference in this report, including, without limitation, statements regarding our future financial position, business strategy, budgets, projected costs and plans and objectives of management for future operations, are forward-looking statements.  In addition, forward-looking statements generally can be identified by the use of forward-looking terminology such as “may,” “will,” “expect,” “intend,” “project,” “estimate,” “anticipate,” “believe,” or “continue” or the negative thereof or variations thereon or similar terminology.  Although we believe that the expectations reflected in such forward-looking statements are reasonable, we cannot give any assurance that such expectations will prove to have been correct.  Important factors that could cause actual results to differ materially from our expectations (“Cautionary Statements”) include, but are not limited to, our assumptions about energy markets, production levels, reserve levels, operating results, competitive conditions, technology, the availability of capital resources, capital expenditure obligations, the supply and demand for oil and natural gas, the price of oil and natural gas, currency exchange rates, the weather, inflation, the availability of goods and services, drilling risks, future processing volumes and pipeline throughput, general economic conditions (either internationally or nationally or in the jurisdictions in which we are doing business), legislative or regulatory changes (including changes in environmental regulation, environmental risks and liability under federal, state and foreign environmental laws and regulations), the securities or capital markets and other factors disclosed above under “Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations” and elsewhere in this report.  All subsequent written and oral forward-looking statements attributable to us, or persons acting on our behalf, are expressly qualified in their entirety by the cautionary statements.  We assume no duty to update or revise our forward-looking statements based on changes in internal estimates or expectations or otherwise.

ITEM 3.    QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

Our primary market risk relates to changes in the pricing applicable to the sales of gas production in the Powder River Basin in Wyoming and Montana.  This risk will become more significant to us as our production increases in these areas.  Although we are not using derivatives at this time to mitigate the risk of adverse changes in commodity prices, we may consider using them in the future.

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ITEM 4.    CONTROLS AND PROCEDURES

As required by SEC rules, we have evaluated the effectiveness of the design and operation of our disclosure controls and procedures at the end of the period covered by this report.  This evaluation was carried out under the supervision and with the participation of our management, including our principal executive officer and principal financial officer.  Based on this evaluation, these officers have concluded that the design and operation of our disclosure controls and procedures are effective.  There were no changes in our internal control over financial reporting or in other factors that have materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.

Disclosure controls and procedures are our controls and other procedures that are designed to ensure that information required to be disclosed by us in the reports that we file or submit under the Exchange 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 by us in the reports that we file under the Exchange Act is accumulated and communicated to our management, including principal executive officer and principal financial officer, as appropriate, to allow timely decisions regarding required disclosure.

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PART II - OTHER INFORMATION

Item 1. Legal Proceedings

We are not a party to any pending legal proceedings.

Item 1A.                                Risk Factors

There were no material changes from the risk factors disclosed in our Form 10-K for the fiscal year ended November 30, 2006.

Item 2. Unregistered Sales of Equity Securities and Use of Proceeds

None.

Item 3. Defaults Upon Senior Securities

None.

Item 4. Submission of Matters to a Vote of Security Holders

None.

Item 5.          Other Information

None.

Item 6. Exhibits

Regulation S-K Number	Exhibit
2.1	Purchase and Sale Agreement Between Dolphin Energy Corporation, and Galaxy Energy Corporation and PetroHunter Operating Company, and PetroHunter Energy Corporation Dated December 29, 2006 (1)
2.2	Second Amendment to Purchase and Sale Agreement dated February 28, 2007 (2)
2.3	Third Amendment to Purchase and Sale Agreement dated March 30, 2007 (3)
2.4	Fourth Amendment to Purchase and Sale Agreement dated April 30, 2007 (4)
2.5	Fifth Amendment to Purchase and Sale Agreement dated May 31, 2007 (5)
2.6	Sixth Amendment to Purchase and Sale Agreement dated June 30, 2007 (6)
2.7	Seventh Amendment to Purchase and Sale Agreement dated July 31, 2007 (7)
3.1	Articles of Incorporation (8)
3.2	Articles of Amendment to Articles of Incorporation (9)(10)

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Regulation S-K Number	Exhibit
3.3	Bylaws (8)
10.1	2003 Stock Option Plan (9)
10.2	Lease Acquisition and Development Agreement between Dolphin Energy Corporation (Buyer/Operator) and Apollo Energy LLC and ATEC Energy Ventures, LLC (Seller/Non-Operator) dated February 22, 2005 (11)
10.3	Participation Agreement between Dolphin Energy Corporation and Marc A. Bruner dated February 23, 2005 (11)
10.4	Securities Purchase Agreement dated March 1, 2005 between Galaxy Energy Corporation and the Buyers named therein (11)
10.5	Form of Note (11)
10.6	Form of Common Stock Purchase Warrant (11)
10.7	Registration Rights Agreement dated March 1, 2005 between Galaxy Energy Corporation and the Buyers named therein (11)
10.8	Subordination Agreement (11)
10.9	Amended Participation Agreement between Marc A. Bruner and Dolphin Energy Corporation dated March 16, 2005 (12)
10.10	Second Amendment to Participation Agreement dated May 24, 2005 (13)
10.11	Securities Purchase Agreement dated May 31, 2005 between Galaxy Energy Corporation and the Buyers named therein (14)
10.12	Form of Note (14)
10.13	Form of Qualifying Issuance Warrants (14)
10.14	Form of Repurchase Warrants (14)
10.15	Form of Registration Rights Agreement (14)
10.16	Form of First Amendment to Security Agreement, Pledge Agreement and Guaranty (14)
10.17	Form of Mortgage Amendment (14)
10.18	Form of Waiver and Amendment to 2004 Notes and Warrants (15)
10.19	Form of Waiver and Amendment to March 2005 Notes and Warrants (14)
10.20	Form of Conveyances of Overriding Royalty Interests (14)
10.21	Form of March 2005 Subordination Agreement (14)
10.22	Second Amendment to Lease Acquisition and Development Agreement (16)

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Regulation S-K Number	Exhibit
10.23	Third Amendment to Participation Agreement dated October 4, 2005 (17)
10.24	Waiver and Amendment dated December 1, 2005 between Galaxy Energy Corporation and the investors named therein (18)
10.25	Securities Purchase Agreement dated April 25, 2006 between Galaxy Energy Corporation and the Buyers named therein (19)
10.26	Form of Debenture (19)
10.27	Form of Warrant (19)
10.28	Form of Subordination Agreement (19)
10.29	Securities Purchase Agreement dated June 20, 2006 between Galaxy Energy Corporation and the Buyers named therein (20)
10.30	Waiver and Agreement dated July 7, 2006 between Galaxy Energy Corporation and the investors named therein (21)
10.31	Subordinated Unsecured Promissory Note dated September 28, 2006 to Bruner Family Trust UTD March 28, 2005 (22)
10.32	Subordination Agreement dated September 28, 2006 (22)
10.33	Subordinated Unsecured Promissory Note dated November 1, 2006 to Bruner Family Trust UTD March 28, 2005 (23)
10.34	Subordination Agreement dated November 1, 2006 (23)
10.35	Subordinated Unsecured Promissory Note dated November 13, 2006 to Bruner Family Trust UTD March 28, 2005 (24)
10.36	Subordination Agreement dated November 13, 2006 (24)
10.37	November 2006 Waiver and Amendment Agreement dated November 29, 2006 among Galaxy Energy Corporation, its subsidiaries and the investors named therein (25)
10.38	Registration Rights Agreement dated November 29, 2006 (25)
10.39	Subordinated Unsecured Promissory Note dated November 30, 2006 to Bruner Family Trust UTD March 28, 2005 (26)
10.40	Subordination Agreement dated November 30, 2006 (26)
10.41	Subordinated Unsecured Promissory Note dated February 1, 2007 to Bruner Family Trust UTD March 28, 2005 (27)
10.42	Subordination Agreement dated February 1, 2007 (27)
10.43	Subordinated Unsecured Promissory Note dated February 26, 2007 to Bruner Family Trust UTD March 28, 2005 (28)
10.44	Subordination Agreement dated February 26, 2007 (28)

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Regulation S-K Number	Exhibit
10.45	Combined Amendment to Lease Acquisition and Development Agreements and to Participation Agreement (29)
10.46	Forbearance Agreement between Galaxy Energy Corporation and Bruner Family Trust UTD March 28, 2005 dated effective December 1, 2006 (30)
10.47	Subordinated Unsecured Promissory Note dated March 30, 2007 to Bruner Family Trust UTD March 28, 2005 (31)
10.48	Subordination Agreement dated March 30, 2007 (31)
10.49	Subordinated Unsecured Promissory Note dated April 25, 2007 to Bruner Family Trust UTD March 28, 2005 (32)
10.50	Subordination Agreement dated April 25, 2007 (32)
10.51	Subordinated Unsecured Promissory Note dated May 4, 2007 to Bruner Family Trust UTD March 28, 2005 (33)
10.52	Subordination Agreement dated May 4, 2007 (33)
10.53	Subordinated Unsecured Promissory Note dated August 31, 2007 to Bruner Family Trust UTD March 28, 2005 (34)
10.54	Subordination Agreement dated August 31, 2007 (34)
10.55	Subordinated Unsecured Promissory Note dated June 29, 2007 to Bruner Family Trust UTD March 28, 2005 (35)
10.56	Subordination Agreement dated June 29, 2007 (35)
10.57	Amended Forbearance Agreement between Galaxy Energy Corporation and Bruner Family Trust UTD March 28, 2005 dated effective June 30, 2007 (36)
10.58	Subordinated Unsecured Promissory Note dated August 22, 2007 to Bruner Family Trust UTD March 28, 2005 (37)
10.59	Subordination Agreement dated August 22, 2007 (37)
10.60	Subordinated Unsecured Promissory Note dated August 29, 2007 to Bruner Family Trust UTD March 28, 2005 (38)
10.61	Subordination Agreement dated August 29, 2007 (38)
10.62	Subordinated Unsecured Promissory Note dated September 28, 2007 to Bruner Family Trust UTD March 28, 2005 (39)
10.63	Subordination Agreement dated September 28, 2007 (39)
10.64	Subordinated Unsecured Promissory Note dated October 11, 2007 to Bruner Family Trust UTD March 28, 2005 (40)
10.65	Subordination Agreement dated October 11, 2007 (40)

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Regulation S-K Number	Exhibit
31.1	Rule 13a-14(a) Certification of Chief Executive Officer
31.2	Rule 13a-14(a) Certification of Chief Financial Officer
32.1	Certification Pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002 of Chief Executive Officer
32.2	Certification Pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002 of Chief Financial Officer

________________

(1) Incorporated by reference to the exhibit to the registrant’s current report on Form 8-K dated December 29, 2006, filed January 4, 2007, file number 0-32237.

(2) Incorporated by reference to the exhibits to amendment no. 1 to the registrant’s current report on Form 8-K dated December 29, 2006, filed March 1, 2007.

(3) Incorporated by reference to the exhibits to amendment no. 2 to the registrant’s current report on Form 8-K dated December 29, 2006, filed April 2, 2007.

(4) Incorporated by reference to the exhibits to amendment no. 3 to the registrant’s current report on Form 8-K dated December 29, 2006, filed May 1, 2007.

(5) Incorporated by reference to the exhibits to amendment no. 4 to the registrant’s current report on Form 8-K dated December 29, 2006, filed June 1, 2007.

(6) Incorporated by reference to the exhibits to amendment no. 5 to the registrant’s current report on Form 8-K dated December 29, 2006, filed July 2, 2007.

(7) Incorporated by reference to the exhibits to amendment no. 6 to the registrant’s current report on Form 8-K dated December 29, 2006, filed August 1, 2007.

 (8) Incorporated by reference to the exhibits to the registrant’s registration statement on Form 10-SB, file number 0-32237.

(9) Incorporated by reference to the exhibits to the registrant’s quarterly report on Form 10-QSB for the quarter ended May 31, 2003, file number 0-32237.

(10) Incorporated by reference to the exhibits to the registrant’s current report on Form 8-K dated October 22, 2004, filed October 26, 2004, file number 0-32237.

(11) Incorporated by reference to the exhibits to the registrant’s current report on Form 8-K dated March 1, 2005, filed March 4, 2005, file number 0-32237.

(12) Incorporated by reference to the exhibits to amendment no. 1 to the registrant’s current report on Form 8-K dated March 1, 2005, filed March 21, 2005.

(13) Incorporated by reference to the exhibits to amendment no. 2 to the registrant’s current report on Form 8-K dated March 1, 2005, filed May 26, 2005.

(14) Incorporated by reference to the exhibits to the registrant’s current report on Form 8-K dated May 31, 2005, filed June 1, 2005, file number 0-32237.

(15) Incorporated by reference to the exhibits to amendment no. 1 to the registrant’s current report on Form 8-K dated May 31, 2005, filed June 2, 2005, file number 0-32237.

(16) Incorporated by reference to the exhibits to amendment no. 3 to the registrant’s current report on Form 8-K dated March 1, 2005, filed June 2, 2005, file number 0-32237.

(17) Incorporated by reference to the exhibits to amendment no. 4 to the registrant’s current report on Form 8-K dated March 1, 2005, filed October 6, 2005, file number 0-32237.

(18) Incorporated by reference to the exhibit to the registrant’s current report on Form 8-K dated December 1, 2005, filed December 2, 2005, file number 0-32237.

(19) Incorporated by reference to the exhibit to the registrant’s current report on Form 8-K dated April 25, 2006, filed April 26, 2006, file number 0-32237.

(20) Incorporated by reference to the exhibit to the registrant’s current report on Form 8-K dated June 20, 2006, filed June 26, 2006, file number 0-32237.

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(21) Incorporated by reference to the exhibit to the registrant’s current report on Form 8-K dated July 7, 2006, filed July 11, 2006, file number 0-32237.

(22) Incorporated by reference to the exhibit to the registrant’s current report on Form 8-K dated September 28, 2006, filed October 3, 2006, file number 0-32237.

(23) Incorporated by reference to the exhibit to the registrant’s current report on Form 8-K dated November 1, 2006, filed November 2, 2006, file number 0-32237.

(24) Incorporated by reference to the exhibit to the registrant’s current report on Form 8-K dated November 13, 2006, filed November 16, 2006, file number 0-32237.

(25) Incorporated by reference to the exhibit to the registrant’s current report on Form 8-K dated November 29, 2006, filed November 30, 2006, file number 0-32237.

(26) Incorporated by reference to the exhibit to the registrant’s current report on Form 8-K dated November 30, 2006, filed December 1, 2006, file number 0-32237.

(27) Incorporated by reference to the exhibit to the registrant’s current report on Form 8-K dated February 1, 2007, filed February 1, 2007, file number 0-32237.

(28) Incorporated by reference to the exhibit to the registrant’s current report on Form 8-K dated February 26, 2007, filed February 27, 2007, file number 0-32237.

(29) Incorporated by reference to the exhibit to the registrant’s current report on Form 8-K dated March 12, 2007, filed March 14, 2007, file number 0-32237.

(30) Incorporated by reference to the exhibit to the registrant’s annual report on Form 10-K for the fiscal year ended November 30, 2006, filed March 15, 2007, file number 0-32237.

(31) Incorporated by reference to the exhibit to the registrant’s current report on Form 8-K dated March 30, 2007, filed April 2, 2007, file number 0-32237.

(32) Incorporated by reference to the exhibit to the registrant’s current report on Form 8-K dated April 25, 2007, filed April 27, 2007, file number 0-32237.

(33) Incorporated by reference to the exhibit to the registrant’s current report on Form 8-K dated May 4, 2007, filed May 8, 2007, file number 0-32237.

(34) Incorporated by reference to the exhibit to the registrant’s current report on Form 8-K dated August 31, 2007, filed June 29, 2007, file number 0-32237.

(35) Incorporated by reference to the exhibit to the registrant’s current report on Form 8-K dated June 29, 2007, filed July 2, 2007, file number 0-32237.

(36) Incorporated by reference to the exhibit to the registrant’s quarterly report on Form 10-Q for the quarter ended May 31, 2007, filed July 16, 2007, file number 1-32682.

(37) Incorporated by reference to the exhibit to the registrant’s current report on Form 8-K dated August 22, 2007, filed August 23, 2007, file number 0-32237.

(38) Incorporated by reference to the exhibit to the registrant’s current report on Form 8-K dated August 29, 2007, filed August 29, 2007, file number 0-32237.

(39) Incorporated by reference to the exhibit to the registrant’s current report on Form 8-K dated September 28, 2007, filed October 2, 2007, file number 0-32237.

(40) Incorporated by reference to the exhibit to the registrant’s current report on Form 8-K dated October 11, 2007, filed October 15, 2007, file number 0-32237.

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SIGNATURES

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

	GALAXY ENERGY CORPORATION
October 22, 2007	By:	/s/  Christopher S. Hardesty
		Christopher S. Hardesty
		Chief Financial Officer

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