NEW FRONTIER ENERGY INC - FORM 10-Q

Attached files

file	filename
EX-32 - EXHIBIT 32 - NEW FRONTIER ENERGY INC	ex32.htm
EX-31.2 - EXHIBIT 31.2 - NEW FRONTIER ENERGY INC	ex31x2.htm
EX-31.1 - EXHIBIT 31.1 - NEW FRONTIER ENERGY INC	ex31x1.htm

SECURITIES AND EXCHANGE COMMISSION

Washington D.C. 20549

FORM 10-Q

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

For the quarterly period ended November 30, 2010

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

For the transition period from __________ to __________

Commission file number: 0-50472

NEW FRONTIER ENERGY, INC.

(Exact name of small business issuer as specified in its charter)

Colorado	84-1530098
(State or other jurisdiction of incorporation or organization)	(I.R.S. Employer Identification No.)

1801 Broadway Suite 920, Denver, CO 80202

(Address of principal executive offices)

(303) 730-9994

(Issuer's telephone number)

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

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

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, or a smaller reporting company.

	Large accelerated filer o	Accelerated filer o
	Non-accelerated filer o	Smaller reporting company x

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

As of March 4, 2011, there were 68,624,558 shares of common stock outstanding.

NEW FRONTIER ENERGY, INC.

Index

Part I - FINANCIAL INFORMATION

Item 1	Financial Statements	2
	Condensed Consolidated Balance Sheet at November 30, 2010 (unaudited) and February 28, 2010	2
	Condensed Consolidated Statements of Operations (unaudited) for the three and nine month period ended November 30, 2010 and 2009	3
	Condensed Consolidated Statements of Cash Flows (unaudited) for the three and nine month period ended November 30, 2010 and 2009	4
	Notes to Condensed Consolidated Financial Statements (unaudited)	5
Item 2	Management’s Discussion and Analysis or Plan of Operations	18
Item 3	Quantitative and Qualitative Disclosures About Market Risk	27
Item 4	Controls and Procedures	27

Part II - OTHER INFORMATION

Item 1	Legal Proceedings	28
Item 1A	Risk Factors	28
Item 2	Unregistered Sales of Equity Securities and Use of Proceeds	28
Item 3	Defaults Upon Senior Securities	28
Item 4	Submission of Matters of a Vote of Security Holders	28
Item 5	Other Information	28
Item 6	Exhibits	28

SIGNATURES		29

EXHIBITS

NEW FRONTIER ENERGY, INC.

CONDENSED CONSOLIDATED BALANCE SHEETS


	November 30,			February 28,
	2010			2010
ASSETS	(unaudited)
CURRENT ASSETS
Cash	$	3,385,519		$	850,202
Accounts receivable - trade, net of allowance for doubtful accounts of $958,429
and $835,132, as of November 30, 2010, and February 28, 2010, respectively		749,386			909,268
Subcription Receivable		-			20,401
Prepaid expenses		414,126			69,151
Inventory		142,425			149,615
Total current assets		4,691,456			1,998,637

PROPERTY AND EQUIPMENT (successful efforts method), at cost:
Oil and gas gathering facilities, net of accumulated depreciation and amortization
of $685,083 and $587,214 as of November 30, 2010, and February 28, 2010, respectively.		1,915,080			2,012,949
Unproved oil and gas properties, net of accumulated depletion, depreciation & amortization
of $1,961,311 and $1,780,486 as of November 30, 2010, and February 28, 2010,
respectively		3,139,325			3,064,345
Other property and equipment, net of accumulated depreciation of $179,530 and
$226,401 as of November 30, 2010 and February 28, 2010, respectively		117,825			105,871
		5,172,230			5,183,165
OTHER ASSETS
Unproved oil and gas properties held for sale		-			577,629
Other property and equipment held for sale, net of accumulated depreciation
of $115,914 as of November 30, 2010, and February 28, 2010, respectively		800,890			851,890
Deposits		3,588			163,288
Total other assets		804,478			1,592,807

Total Assets	$	10,668,164		$	8,774,609

LIABILITIES AND STOCKHOLDERS' EQUITY
CURRENT LIABILITIES
Accounts payable	$	827,854		$	1,613,114
Notes payable, current portion		201,563			836,563
Notes payable - affiliate		50,000			-
Dividends payable		1,197,471			1,030,565
Total current liabilities		2,276,888			3,480,242

LONG TERM LIABILITIES
Derivative liability		520,000			480,000
Contingent liability - deferred gain		1,856,766			-
Asset retirement obligation		82,871			77,000
Total long term liabilities		2,459,637			557,000

Total liabilities		4,736,525			4,037,242

Commitements and contingencies (Notes 3 and 8)

STOCKHOLDERS' EQUITY
New Frontier Energy, Inc stockholders' equity:
Preferred stock, $.001 par value, 25,000,000 shares authorized:
Series A Convertible, 100,000 shares authorized, none issued and outstanding		-			-
Series B Convertible, 36,036 shares authorized, 18,798 and 18,949 issued and
as of November 30, 2010, and February 28, 2010, respectively, aggregate
liquidation preference of $1,879,800		18			19
Series C Convertible, 230,000 shares authorized, none issued and outstanding		-			-
Common stock, $.001 par value, 500,000,000 shares authorized, 68,029,379 and
67,990,662 shares issued and outstanding as of August 31, 2010 and
February 28, 2010, respectively		68,029			67,991
Additional paid in capital		26,116,091			26,001,033
Accumulated deficit		(20,744,464	)		(21,758,475	)
Total New Frontier Energy, Inc. stockholders' equity		5,439,674			4,310,568
Noncontrolling interest		491,965			426,799
Total stockholders' equity		5,931,639			4,737,367

Total liabilities and stockholders' equity	$	10,668,164		$	8,774,609

See accompanying notes to the condensed consolidated financial statements.

NEW FRONTIER ENERGY, INC.

CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS

(unaudited)


	Nine months ended						Three months ended
	November 30,						November 30,
	2010			2009			2010			2009
Operating revenues:
Oil and gas sales	$	104,499		$	146,893		$	38,569		$	44,511
Gathering and operating income		399,172			113,139			4,670			25,200
Total oil and gas revenue		503,671			260,032			43,239			69,711

Operating expenses:
Exploration costs, including dry holes		638,176			76,411			302,433			4,128
Lease operating expenses		75,803			302,706			37,029			28,811
Cost of gas gathering		-			2,235			-			1,584
General and administrative		865,386			2,992,678			216,413			799,636
Impairment expense		51,000			809,721			-			-
Depreciation, depletion and amortization		270,108			363,657			101,035			61,866
Total operating expenses		1,900,473			4,547,408			656,910			896,025

Loss from operations		(1,396,802	)		(4,287,376	)		(613,671	)		(826,314	)

Other income (expense):
Change in fair value of derivative financial instruments		(40,000	)		3,220,000			30,000			150,000
Other income		2,715,447			103,294			24,383			103,294
Interest income (expense), net		(23,497	)		(51,955	)		5,299			(25,152	)
Other income, net		2,651,950			3,271,339			59,682			228,142

Income (loss) before income taxes and noncontrolling interest		1,255,148			(1,016,037	)		(553,989	)		(598,172	)

Income taxes		-			-			-			-

Net income (loss) before noncontrolling interest		1,255,148			(1,016,037	)		(553,989	)		(598,172	)

Net (income) attributable noncontrolling interest		(65,166	)		(26,977	)		9,170			(13,933	)

Net income (loss)		1,189,982			(1,043,014	)		(544,819	)		(612,105	)

Preferred stock dividends and distributions		(175,971	)		(562,825	)		(58,582	)		(191,638	)

Net income (loss) attributable to common shareholders	$	1,014,011		$	(1,605,839	)	$	(603,401	)	$	(803,743	)

Net income (loss) per common share
Basic	$	0.01		$	(0.11	)	$	(0.01	)	$	(0.05	)
Diluted	$	0.01		$	(0.11	)	$	(0.01	)	$	(0.05	)

Weighted average shares outstanding
Basic		68,302,348			14,921,425			68,404,380			17,592,449
Diluted		74,377,348			14,921,425			68,404,380			17,592,449

See accompanying notes to the condensed consolidated financial statements.

NEW FRONTIER ENERGY, INC.

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

(unaudited)


	Nine months ended
	November 30,
	2010			2009
CASH FLOWS FROM OPERATING ACTIVITIES:
Net income (loss)	$	1,255,148		$	(1,016,037	)
Adjustments to reconcile net loss to net cash
(used in) provided by operating activities:
Depreciation, depletion and amortization		270,108			363,657
Bad debt expense		123,297			-
Impairment and abandonment of of oil and gas properties		51,000			809,721
Share-based compensation expenses, amortization and grants		165,096			2,042,820
Increase (decrease) in liability fair value from derivative liability		40,000			(3,220,000	)
(Gain) Loss from sale of asset, net of deferred gain of $1.8 million		(2,703,437	)		-
(Increase) decrease in assets:
Accounts receivable, trade		36,585			(1,602,119	)
Subscription receivable		20,401			-
Prepaid expenses and deposits		(185,275	)		(97,242	)
Increase (decrease) in liabilities:
Accounts payable and accrued expenses		(785,260	)		1,431,668
Other		-			(100	)
Net cash used in operating activities		(1,712,337	)		(1,287,632	)

CASH FLOWS FROM INVESTING ACTIVITIES:
Proceeds from sale of oil and gas property		3,226,185			-
Proceeds from Entek participation agreement		-			1,000,000
Proceeds from sale of Inventory		31,573			-
Purchase of property and equipment		(222,805	)		(19,708	)
Net cash provided by investing activities		3,034,953			980,292

CASH FLOWS FROM FINANCING ACTIVITIES:
Payment of notes payable		(635,000	)		(200,898	)
Contingent repurchase option		1,856,766			-
Proceeds from sale of common stock		-			1,000,000
Preferred stock dividends paid		(9,065	)		-
Distributions to minority interest holders in consolidated subsidiary		-			(45,991	)
Other		-			9,656
Net cash provided by financing activities		1,212,701			762,767

INCREASE IN CASH		2,535,317			455,427

BEGINNING BALANCE		850,202			856,475

ENDING BALANCE	$	3,385,519		$	1,311,902

Cash paid for income taxes	$	-		$	-

Cash paid for interest	$	-		$	13,181


Supplemental schedule of non-cash investing and financing activities:
Conversion of Series B Preferred Stock to Common Stock	$	39		$	2,063
Exchange of stock options for note payable	$	50,000		$	-

See accompanying notes to the condensed consolidated financial statements.

NEW FRONTIER ENERGY, INC.

NOTES TO UNAUDITED CONSOLIDATED FINANCIAL STATEMENTS

November 30, 2010

Note 1 – The Company and Business

The Company and Business

New Frontier Energy, Inc. (“NFEI” or the “Company”) is an independent energy company engaged in the exploration, development, acquisition, and production of natural gas and crude oil. The Company’s operations are conducted entirely in the continental United States, principally in the Green River Basin (“GRB”) in Colorado and Wyoming, the Denver Julesburg Basin (“DJ Basin”) in Colorado and in the Calcasieu and Jefferson Davis Parishes in Louisiana (“Amazon Prospect”).

Note 2 – Basis of Presentation and Significant Accounting Policies

Basis of Presentation

The unaudited condensed consolidated financial statements include the accounts of NFEI and Slater Dome Gathering, LLLP (“SDG”) and have been prepared in accordance with accounting principles generally accepted in the United States (“GAAP”) for interim financial information. Pursuant to the rules and regulations of the Securities and Exchange Commission (“SEC”), they do not include all of the information and footnotes required by GAAP for complete financial statements. In the opinion of management, the accompanying unaudited condensed consolidated financial statements include all adjustments (consisting of normal and recurring accruals) considered necessary to present fairly in all mutual respect the Company’s financial position as of November 30, 2010, the Company’s results of operations for the nine month period ended November 30, 2010 and 2009, and cash flows for the nine month period ended November 30, 2010 and 2009. Operating results for the nine month period ended November 30, 2010, are not necessarily indicative of the results that may be expected for the fiscal year ending February 28, 2011, because of the impact of fluctuations in prices received for natural gas and crude oil, natural production declines, the uncertainty of exploration and development drilling results and other factors.

Certain prior period amounts have been reclassified to conform to the current period presentation.

Principles of Consolidation

The November 30, 2010, unaudited condensed consolidated financial statements include the accounts of NFEI as of and for the reporting periods ended November 30, and include the accounts of SDG as of and for the reporting periods ended September 30. SDG has a calendar fiscal year end of December 31, which is consolidated with the Company effective February 28. The creditors of SDG do not have recourse to the general credit of the Company. All significant intercompany transactions have been eliminated upon consolidation.

Use of Estimates in the Preparation of Financial Statements

The preparation of the consolidated financial statements in conformity with GAAP requires management to make estimates and assumptions that affect the reported amounts of oil and gas reserves, assets and liabilities, disclosure of contingent assets and liabilities at the date of the financial statements, and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates.

Earnings per Common Share

Basic net earnings per common share is calculated by dividing net earnings available to common stockholders by the weighted-average basic common shares outstanding for the respective period.

Diluted net earnings per common share of stock is calculated by dividing adjusted net earnings by the weighted-average diluted common shares outstanding, which includes the effect of potentially dilutive securities. Potentially dilutive securities for the diluted earnings per share calculation consist of outstanding in-the-money stock options and warrants to purchase the Company’s common stock and the Series B and C Preferred Stock (defined in Note 6 – Stockholders’ Equity).

The treasury stock method is used to measure the dilutive impact of stock options, warrants and Series B and C Preferred Stock. In accordance with FASB ASC Topic 260, “Earnings Per Share,” when there is a loss from continuing operations, all potentially dilutive shares will be anti-dilutive.

The following table sets forth the calculation of basic and diluted earnings per share attributable to common shareholders:

	For the nine month period					For the three month period
	ended November 30,					ended November 30,
	2010		2009			2010			2009
Net income (loss) available to common shareholder’s – Basic	$	1,014,011	$	(1,605,839	)	$	(603,401	)	$	(803,743	)
Plus: Preferred stock dividends		175,971		-			-			-
Net income (loss) available to common shareholder’s - Diluted	$	1,189,982	$	(1,605,839	)	$	(603,401	)	$	(803,743	)

Basic weighted-average common shares outstanding		68,302,348		14,921,425			68,404,380			17,592,449
Add: dilutive effect of preferred stock		4,825,000		-			-			-
Add: dilutive effect of stock options and warrants		1,250,000		-			-			-
Diluted weighted average common shares outstanding		74,377,348		14,921,425			68,404,380			17,592,449
Basic net income (loss) per common share	$	0.01	$	(0.11	)	$	(0.01	)	$	(0.05	)
Diluted net income (loss) per common share	$	0.01	$	(0.11	)	$	(0.01	)	$	(0.05	)

Pursuant to the automatic conversion provision of the Series C Preferred Stock, on December 1, 2009, all 216,000 shares of Series C Preferred Stock outstanding converted into 34,099,265 common shares. In addition, during fiscal year ended February 28, 2010, the Company issued 2,056,000 shares of common stock to one of the Company’s Director’s as a structuring fee and 375,000 to its President and CEO as compensation and an additional 18,000,000 shares of common stock were sold to two accredited investors, which included an affiliate to the Company.

Other Significant Accounting Policies

The accounting policies followed by the Company are set forth in Note 1 to the Company’s consolidated financial statements in the 2010 Form 10-K, and are supplemented throughout the notes to these unaudited condensed consolidated financial statements in this report. It is suggested that these condensed consolidated financial statements be read in conjunction with the consolidated financial statements and notes included in the 2010 Form 10-K.

Accounting Standards Update

In January 2010, the Financial Accounting Standards Board (“FASB”) issued additional guidance intended to improve disclosure requirements related to fair value measurements and disclosures. Specifically, this guidance requires disclosures about transfers in and out of Level 1 and 2 fair value measurements, activity in Level 3 fair value measurements (see Note 7 for Level 1, 2 and 3 definitions), greater disaggregation of the amounts on the unaudited condensed consolidated balance sheets that are subject to fair value measurements and additional disclosures about the valuation techniques and inputs used in fair value measurements. This guidance is effective for interim and annual reporting periods beginning after December 31, 2009, except for disclosure of Level 3 fair value measurement roll forward activity, which is effective for annual reporting periods beginning after December 15, 2010. This guidance was adopted in the first quarter of 2011 and had no impact on the unaudited condensed consolidated financial statements other than the additional disclosures.

In April 2010, the FASB issued ASU 2010-14, "Accounting for Extractive Activities — Oil & Gas." ASU 2010-14 amends paragraph 932-10-S99-1 due to SEC Release No. 33-8995, "Modernization of Oil and Gas Reporting." The amendments to the guidance on oil and gas accounting did not have an impact on the Company's financial position.

There were various other updates recently issued, most of which represented technical corrections to the accounting literature or application to specific industries and are not expected to a have a material impact on the Company's consolidated financial position, results of operations or cash flows.

Note 3 – Acquisitions, Divestitures and Assets Held for Sale

Acquisitions

There were no significant acquisitions during the nine month period ended November 30, 2009.

On September 1, 2010 (effective date of April 1, 2010), NFEI entered into a Joint Exploration Agreement (the “Agreement”) with Yuma Exploration and Production Company, Inc. (“Yuma”), whereby NFEI will participate as a ten-percent working interest owner in the shooting, processing and interpretation of a 70 square mile 3-D seismic survey, the generation of prospects, the acquisition of leases, and the exploration, development and production of oil and gas prospects generated from the 3-D seismic in the Amazon Prospect in the Calcasieu and Jefferson Davis Parishes in Louisiana.

Divestitures

On June 4, 2010, NFEI entered into a Purchase and Sale Agreement with Carrizo Oil & Gas, Inc. (“Carrizo”) to sell its interest in certain oil and gas leases (the “Leases”) in the DJ Basin in Weld and Morgan Counties, Colorado.

Pursuant to the Purchase and Sale Agreement, Carrizo must drill not less than three Carry Wells (as defined in the Purchase and Sale Agreement) in the 18 months following the closing (the “Drilling Period”) on the sale of the interest in the Leases and carry the Company for a 33 1/3 percent working interest in each of these wells (subject to adjustment as provided in the Purchase and Sale Agreement). In the event that Carrizo fails to commence the drilling of the three Carry Wells during the Drilling Period, the Leases (except for 640 acre tracts) shall be reassigned back to the Company.

Pursuant to the Purchase and Sale Agreement, if Carrizo commences drilling three Carry Wells before the end of the Drilling Period, the Company has the option to repurchase an undivided one-third working interest in the Leases. To repurchase the one-third working interest in the Leases, the Company shall pay one-third of the total amount Carrizo paid to the Company, plus one-third of any amount Carrizo has paid to renew, extend or replace the Leases during the Drilling Period.

In connection with the Purchase and Sale Agreement, the Company and Carrizo also entered into an AMI Agreement whereby the Company and Carrizo agreed to create an area of mutual interest in all governmental sections within which the Company owns Leases as of June 4, 2010 (subject to certain exclusions)(the “AMI Territory”). Pursuant to the AMI Agreement, the Company and Carrizo granted the other party the option acquire its proportionate interest, (33 1/3% in the case of the Company and 66 2/3% in the case of Carrizo) in any oil and gas leases and other interests in the AMI Territory.

The Company received an initial advance from the sale of the interest in the Leases of $5,519,989 and an additional $50,307 upon verification of certain Leases. The Company treated this transaction as a sale of a partial interest in an unproved property. Pursuant to ASC 470-40 Product Financing, when a transaction in which an entity sells inventory (oil and gas property in this case) and agrees to repurchase the inventory with a repurchase price equal to the original sales price, a financing arrangement exists. Therefore, the Company recorded a gain on sale to the extent that two-thirds of the proceeds ($3,713,531) are recognized as proceeds received. The remaining one-third ($1,856,766) was treated as a financing arrangement, resulting in $1,856,766 being reflected as a deferred gain on the unaudited condensed consolidated balance sheet and as a financing activity in the unaudited condensed consolidated statement of cash flows.

If this option is exercised, the Company will tender $1,856,766, plus 1/3 of any amount Carrizo has paid to renew, extend or replace the Leases during the Drilling Period to Carrizo in exchange for a 33 1/3 interest assignment in the Leases, which will satisfy the contingent liability. However, if the option expires unexercised, the Company will recognize an additional $1,856,766 as a gain on sale of unproved property.

On August 10, 2009, the Company entered into a Participation Agreement (the “Participation Agreement”) with Entek GRB LLC (“Entek”) under which Entek has the right to participate and earn assignments of NFEI’s interest up to 55% through three phases in the exploration and development of certain oil and gas properties within approximately 66,000 gross acres in the Green River Basin (the “Underlying Leases”) and certain of its other assets, including its partnership interests in Slater Dome Gathering, LLLP (collectively the “Assets”). The Company and Entek also created an area of mutual interest (the “Area of Mutual Interest”) in all lands located in Routt County, Colorado, Moffatt County, Colorado, Sweetwater County, Wyoming, and Carbon County Wyoming. Pursuant to the Area of Mutual Interest, Entek shall be entitled to participate for up to 55% in any additional interest acquired within the Area of Mutual Interest by the Company and the Company shall be entitled to participate for up to 45% in any additional interest acquired within the Area of Mutual Interest.

In February 2010, Entek completed its obligation for Phase I and earned an additional 16.25% of the Company’s interest in the Assets for an aggregate of 20.3125% of the Company’s interest in the Assets as of November 30, 2010.

Assets Held for Sale

In accordance with ASC Topic 360, “Property, Plant and Equipment” assets are classified as held for sale when the Company commits to a plan to sell the assets and there is reasonable certainty that the sale will take place within one year. Upon classification as held for sale, long-lived assets are no longer depreciated or depleted and a measurement for impairment is performed to expense any excess of carrying value over fair value less costs to sell. Subsequent changes to estimated fair value less the cost to sell will impact the measurement of assets held for sale for assets for which fair value is determined to be less than the carrying value of the assets.

As of November 30, 2010, the accompanying unaudited condensed consolidated balance sheet includes approximately $801,000 in book value recorded as an asset held for sale, net of accumulated DD&A, impairment and selling costs. The above asset held for sale is for the Steamboat Property. The Company recorded an impairment related to this property in the amount of $51,000 during the nine month period ended November 30, 2010. There were no assets held for sale during the nine month period ended November 30, 2009, therefore there was no measurement for impairment. The Company began marketing this asset in the fourth quarter of fiscal year ended February 28, 2010. The Company determined that this asset does not qualify for discontinued operations accounting under ASC Topic 205.

Note 4 - Notes payable

Natural Resource Group Gathering Note Payable

Effective December 31, 2007, the Company entered into a Purchase and Sale Agreement with Natural Resource Group Gathering, LLC (“NRGG”), whereby the Company increased its investment in Slater Dome Gathering, LLLP (“SDG”) by acquiring the general partner’s interest for $1,075,000 consisting of $268,750 in cash and executing a promissory note (the “Note”) in the amount of $806,250. The Note accrues interest at a rate of 2.5% per annum and is payable in quarterly installments of $201,562 plus interest. The terms of this note were modified on December 24, 2008, and subsequently on July 29, 2009, which extended the date and payment terms, whereby the then outstanding principal balance together with all accrued and unpaid interest will be due December 31, 2010. The Note may be prepaid at any time without penalty. At the option of the Company, quarterly payments may be deferred until the maturity date. The balance of this note payable at August 31, 2010, was $201,563. On December 31, 2010, Entek made a payment for the full amount on behalf of NFEI satisfying this debt as part of the Participation Agreement.

Paul G. Laird, the Company’s former President and CEO is a manager and owns 50% of the membership interest of NRGG.

Steamboat Property Note Payable

On June 15, 2007, the Company acquired real property in Steamboat Springs, CO (the “Steamboat Property”). The purchase price for the Steamboat Property was $1,175,000. In connection with the purchase of the Steamboat Property, the Company entered into a five-year mortgage in the principal amount of $881,250 (the “Steamboat Mortgage”). On July 7, 2009, the former President and CEO, as nominee for the Company, entered into a new mortgage in the amount of $635,000 (the “New Steamboat Mortgage”). The New Steamboat Mortgage had a one year term due July 6, 2010, and accrued interest at the rate of prime plus 400 basis points with a floor of 10% and collateralized by the Steamboat Property. As a condition of the New Steamboat Mortgage, interest in the amount of $63,500 was prepaid. The Company had the option to prepay the New Steamboat Mortgage in full, or in part, without penalty with any the unamortized prepaid interest being returned to the Company.

In June 2010, the former President and CEO executed a Quit Claim Deed assigning title for the Steamboat Property back to the Company. Concurrently with the execution of the Quit Claim Deed, NFEI made a payment in full satisfaction of the Steamboat Mortgage.

Note Payable - affiliates

On December 31, 2010, one of the Company’s directors elected to exchange his stock options for a $50,000 note payable, with an interest rate equal to the 1-month London Interbank Offered Rate (“LIBOR”), with such accrued and unpaid interest along with the principal to be paid on the maturity date of December 31, 2012.

Note 5 - Asset Retirement Obligations

The Company recognizes an estimated liability for future costs associated with the abandonment of its oil and gas properties. A liability for the fair value of an asset retirement obligation and a corresponding increase to the carrying value of the related long-lived asset are recorded at the time a well is completed or acquired. The increase in carrying value is included in proved oil and gas properties in the accompanying consolidated balance sheets. The Company depletes the amount added to proved oil and gas property costs and recognizes expense in connection with the accretion of the discounted liability over the remaining estimated economic lives of the respective oil and gas properties. Cash paid to settle asset retirement obligations is included in the operating section of the Company’s accompanying unaudited consolidated statements of cash flows.

The Company’s estimated asset retirement obligation liability is based on historical experience in abandoning wells, estimated economic lives, estimates as to the cost to abandon the wells in the future, and federal and state regulatory requirements. The liability is discounted using the credit-adjusted risk-free rate estimated at the time the liability is incurred or revised. The credit-adjusted risk-free rate used to discount the Company’s abandonment liabilities is 10.0 percent. Revisions to the liability could occur due to changes in estimated abandonment costs or well economic lives, or if federal or state regulators enact new requirements regarding the abandonment of wells. Asset retirement obligations are valued using Level 3 fair value measurement inputs.

A reconciliation of the Company’s asset retirement obligation liability is as follows:

	November 30,
	2010
Beginning asset retirement obligation	$	77,000
Liabilities incurred		-
Revisions to estimated future plugging liability		-
Accretion expense		5,871
Total Asset retirement obligation	$	82,871

Note 6 - Stockholders’ Equity

Series A Convertible Preferred Stock

There were no shares of Series A convertible Preferred Stock, par value $0.001 issued or outstanding as of November 30, 2010, and February 28, 2010. Such shares may be issued with such preferences and in such series as determined by the Board of Directors.

Series B Convertible Preferred Stock

The Series B Preferred Stock contain an anti-dilution provision which provides for conversion price adjustments (“down round protection”), which requires the fair value of these conversion features to be bifurcated and presented separately as a derivative liability on the consolidated balance sheets. The fair value of these financial instruments is remeasured each quarter with the change being reflected in the consolidated statements of operations as a “Change in fair value of derivative financial instruments” (see Note 7 – Fair Value Measurements).

In March 2010, the company issued an aggregate 28,717 shares of common stock pursuant to conversion of 112 shares of Series B Preferred Stock.

In July 2010, the company issued an aggregate 10,000 shares of common stock pursuant to conversion of 39 shares of Series B Preferred Stock.

As of November 30, 2010, and February 28, 2010, there were 18,798 and 18,949 shares of Series B Preferred Stock issued and outstanding. During the six month period ended August 31, 2010, dividends of $175,971 were accrued and $9,065 cash dividends were paid. Aggregate accrued and unpaid dividends totaled $1,197,471 as of November 30, 2010.

Series C Convertible Preferred Stock

Effective December 1, 2009, pursuant to the automatic conversion provision, the then outstanding 216,000 shares of Series C preferred stock and the associated accumulated dividends were converted into an aggregate 34,099,265 shares of common stock.

As of November 30, 2010 and February 28, 2010, there were no shares of Series C Preferred Stock issued and outstanding.

Common Stock

The authorized common stock of the Company consists of 500,000,000 common shares with a par value of $0.001. The holders of the common shares are entitled to one vote for each share of common stock. As of November 30, 2010 and February 28, 2010, there were 68,029,379 shares (78,864 which have not been issued due to technical reasons) and 67,990,662 shares outstanding, respectively.

Stock Options and Warrants

The Company charged $165,096 and $1,611 of stock based compensation during the nine and three month periods ended November 30, 2010, respectively, and charged $2,042,820 and $566,058 during the nine and three month periods ended November 30, 2009, respectively. Stock based compensation is included in general and administrative expense.

Effective May 11, 2010, the Company’s Board of Directors approved the issuance of 500,000 options to acquire shares of the Company’s common stock exercisable at a price of $0.50 per share and a fair value of $0.06 per share with an expiration date of December 31, 2011, to the Company’s Chief Financial Officer. These shares vest on December 1, 2011 and the fair value of $30,600 is being realized over the requisite service period and included in general and administrative expense.

The following assumptions were used for the options granted during the nine month period ended November 30, 2010, and for the fiscal year ended February 28, 2010:

	November 30, 2010	February 28, 2010
Expected option life (in years)	1.50	1 to 5
Expected annual volatility over option life	175%	87% to 214%
Risk-free interest rate	0.9%	0.3% to 3.8%
Pre-vesting forfeiture rate	0%	0%
Dvidend yield	0%	0%

The activity for options during the nine month period ended November 30, 2010, is summarized in the following tables:

Non-Incentive Stock Options, November 30, 2010:

Options	Number of shares			Weighted avg exercise price		Wtd avg remaining contractual term		Aggregate intrinsic value
Outstanding at February 28, 2010		7,854,166		$	1.13
Granted		500,000		$	0.50
Exercised		-		$	-
Forfeited or expired		(2,045,833	)	$	1.01
Outstanding at November 30, 2010		6,308,333		$	1.12		3.88	$	-
Exercisable at November 30, 2010		5,808,333		$	1.17		4.12	$	-

Incentive Stock Option Shares, November 30, 2010:

Options	Number of shares		Weighted avg exercise price		Wtd avg remaining contractual term		Aggregate intrinsic value
Outstanding at February 28, 2010		115,000	$	0.81
Granted		-	$	-
Exercised		-	$	-
Forfeited or expired		(115,000)	$	0.81
Outstanding at November 30, 2010		-	$	-		-	$	-
Exercisable at November 30, 2010		-	$	-		-	$	-

Fixed-Price Stock Options and Warrants, November 30, 2010:

Options	Number of shares		Weighted avg exercise price		Wtd avg remaining contractual term		Aggregate intrinsic value
Outstanding at February 28, 2010		4,300,000	$	0.52
Granted		-	$	-
Exercised		-	$	-
Forfeited or expired		-	$	-
Outstanding at November 30, 2010		4,300,000	$	0.52		0.95	$	12,500
Exercisable at November 30, 2010		4,300,000	$	0.52		0.95	$	12,500

The following table summarizes the options and warrants outstanding at November 30, 2010:

Range of Exercise Price	Weighted Average Remaining Contractual Life in Years		Number of Shares Outstanding		Number of Shares Exercisable		Weighted Average Exercise Price		Aggregate Intrinsic Value

$0.20 to $0.74		1.35		4,250,000		3,750,000	$	0.33	$	12,500
40.75 to $1.50		4.37		5,808,333		5,808,333	$	1.17	$	-
$1.51 to $2.50		0.21		550,000		550,000	$	2.00	$	-
Total		2.94		10,608,333		10,108,333	$	0.88	$	-

The total estimated unrecognized compensation cost from unvested stock options as of November 30, 2010, was $25,767, which is expected to be recognized over a weighted average period of approximately one year.

Note 7 – Fair Value Measurements

FASB ASC Topic 820, Fair Value Measurements and Disclosures, defines fair value as the price that would be received to sell an asset or paid to transfer a liability (an exit price) in an orderly transaction between market participants at the measurement date. The guidance establishes market or observable inputs as the preferred sources of values, followed by assumptions based on hypothetical transactions in the absence of market inputs. The guidance establishes a hierarchy for determining the fair values of assets and liabilities, based on the significance level of the following inputs:

·	Level 1 – Quoted prices in active markets for identical assets or liabilities

·	Level 2 – Quoted prices in active markets for similar assets and liabilities, quoted prices for identical or similar instruments in markets that are not active, and model-derived valuations whose inputs are observable or whose significant value drivers are observable

·	Level 3 – Significant inputs to the valuation model are unobservable.

An asset or liability subject to the fair value requirements is categorized within the hierarchy based on the lowest level of input that is significant to the fair value measurement. NFEI’s assessment of the significance of a particular input to the fair value measurement in its entirety requires judgment and considers factors specific to the asset or liability.

Both financial and non-financial assets and liabilities are categorized within the hierarchy based on the lowest level of input that is significant to the fair value measurement.

The following is a listing of the Company’s financial liabilities measured on a recurring basis and where it is classified within the hierarchy as of November 30, 2010:

Fair value measurements using:

Liabilities at fair values:

Total

Level 1

Level 2

Level 3

Derivative liability – Series B Preferred Stock

520,000

There were no nonfinancial assets and liabilities measured at fair value on a nonrecurring basis at November 30, 2010.

The following is a listing of the Company’s assets and liabilities that are measured at fair value and where they are classified within the hierarchy as of February 28, 2010:

	Fair value measurements using:
	Total		Level 1		Level 2		Level 3
Assets:
Oil and gas properties (a)		1,206,366		-		-		1,206,366
Materials inventory (a)		149,615		-		149,615		-
Liabilities:
Derivative - Series B Preferred (b)		480,000		-		-		480,000

_________________________

(a)	This represents a nonfinancial asset that is measured at fair value on a nonrecurring basis.

(b)	This represents a financial liability that is measured at fair value on a recurring basis.

Proved Oil and Gas Properties

Proved oil and gas property costs will be evaluated for impairment and reduced to fair value if the sum of the expected undiscounted future cash flows is less than net book value pursuant to ASC Topic 360. The Company will use Level 3 inputs and the income valuation technique, which converts future amounts to a single present value amount, to measure the fair value of proved properties through an application of discount rates and price forecasts selected by the Company’s management based on current market conditions which includes the following factors: estimate of future cash payments, expectations of possible variations in the amount and/or timing of cash flows, the risk premium, and nonperformance risk. The Company currently has no proved oil and gas property at November 30, 2010 and 2009.

Unproved oil and gas property will be evaluated for impairment when the Company determines that either the property will not be developed or the carrying value will not be realized. The Company will use Level 3 inputs based on management’s internal assessment of the valuation based on current market conditions, which include observable and unobservable inputs. Of the $5,422,461of unproved property, $1,206,366 was measured at fair value using Level 3 inputs at February 28, 2010. There were no unproved properties measured at fair value at November 30, 2010.

Materials Inventory

Materials inventory is valued at the lower of cost or market. The Company uses Level 2 inputs to measure the fair value of materials inventory, which is primarily comprised of tubular goods. The Company uses third party market quotes and compares the quotes to the book value of the materials inventory. If the book value exceeds the quoted market price, the Company reduces the book value to the market price. The considered factors result in an estimated exit-price that management believes provides a reasonable and consistent methodology for valuing materials inventory. The Company’s entire materials inventory was measured at fair value using Level 2 inputs at February 28, 2010. There were no materials inventory measured at fair value at November 30, 2010.

Asset Retirement Obligations

The Company estimates asset retirement obligations pursuant to the provisions of ASC Topic 410. The income valuation technique is utilized by the Company to determine the fair value of the liability at the point of inception by applying a credit-adjusted risk-free rate, which takes into account the Company’s credit risk, the time value of money, and the current economic state, to the undiscounted expected abandonment cash flows. Given the unobservable nature of the inputs, the initial measurement of the asset retirement obligation liability is deemed to use Level 3 inputs. There were no asset retirement obligations measured at fair value at November 30, 2010.

Conversion Feature Embedded in the Series B Preferred Stock

The estimated fair values of the derivative liabilities embedded within the Series B preferred shares were determined at each reporting period using a monte carlo option pricing model with Level 3 inputs.

The Company had no Level 1 or Level 2 financial assets or liabilities that were measured at fair value on a recurring basis as of November 30, 2010. The following table reflects the Level 3 activity for the conversion feature measured at fair value on a recurring basis for the nine and three month periods ended November 30, 2010 and 2009:

	For the Nine Months							For the Three Months
	Ended November 30,							Ended November 30,
	2010			2009				2010				2009
Beginning balance		$	480,000		$	3,740,000			$	550,000			$	670,000
Net increase (decrease) in liability			40,000			(3,220,000	)			(30,000	)			(150,000	)
Transfers in (out) of Level 3			-			-				-				-
Ending balance		$	520,000		$	520,000			$	520,000			$	520,000

The fair values of the embedded derivative liabilities for the Series B preferred shares were determined using the following key assumptions:

	Expected volatility		Expected dividend yield		Time to maturity		Credit-adjusted-risk-free-rate per annum		Strike Price		Fair value of underlying common shares (per share)
November 30, 2010	119% to 226%		0%		1 to 7 yrs		10%		$0.65		$ 0.21

Note 8 – Commitments

Operating Leases

For the six month period ended August 31, 2010 and 2009, month-to-month office facilities rental payments charged to expense were approximately $19,501 and $16,000, respectively. Future rental payments for office facilities under the terms of noncancelable operating leases were approximately $23,423 as of November 30, 2010.

As of November 30, 2010, the Company does not have any office facility leases in effect for 2013 and beyond.

Note 9 - Related Parties

The Company paid $0 and $24,000 during the nine month period ended November 30, 2010 and 2009, respectively, in connection with an office lease for office space in Littleton, Colorado with Spotswood Properties, LLC, (“Spotswood”), a Colorado limited liability company and an affiliate of the Company’s former President and CEO. This lease was terminated in December 2009 and the Company has entered into a new lease with an unaffiliated company.

The Company paid a corporation controlled by one of the former directors and a shareholder $0 and $15,625 for geological consulting during the nine month period ended November 30, 2010 and 2009, respectively.

See also Note 4 – Notes payable, Note 6 – Stockholders’ equity and Note 8 - Commitments

Note 10 - Legal Proceedings

Slaterdome Gas, Inc. Litigation

On or about July 20, 2010, the Company brought an action (the “Slaterdome Complaint”) for breach of contract, unjust enrichment and foreclosure of contractual liens against Slaterdome Gas, Inc. to recover unpaid debts in connection with an Operating Agreement that the Company and Slaterdome Gas, Inc. are parties to covering certain lands in Moffat County, Colorado and Carbon County, Wyoming (District Court, Moffat County, Colorado 2010CV65). The Company is seeking to recover damages in an amount to be proven at trial and for the foreclosure of a contractual lien on certain property owned by Slaterdome Gas, Inc. On November 7, 2010, Slaterdome Gas, Inc. filed an answer and counterclaim against the Company asserting various defenses to the Slaterdome Complaint and asserts a claim for specific performance for the assignment of certain oil and gas rights on certain lands in Moffat County, Colorado and Carbon County, Wyoming and to quiet title to such oil and gas rights. As of the date of this Interim Report, the outcome of this matter cannot be determined.

Note 11 – Business Segment Information

The Company operates in two business segments: oil and gas exploration and gas gathering. Operating results and other financial data for the nine and three month period ended November 30, 2010 and 2009, is presented for the principal business segments as follows:


Nine months ended November 30, 2010:	Oil & Gas				Gas Gathering				Consolidated
Revenues		$	104,499			$	399,172			$	503,671
Income (loss) before taxes		$	1,055,723			$	199,425			$	1,255,148
Total assets		$	8,209,141			$	2,459,023			$	10,668,164
Property additions		$	222,805			$	-			$	222,805
Other income (expense)		$	3,103,679			$	48,271			$	3,151,950
Depreciation, depletion and amortization		$	(172,239	)		$	(97,869	)		$	(270,108	)



Nine months ended November 30, 2009:	Oil & Gas			Gas Gathering			Consolidated
Revenues	$	146,893		$	113,139		$	260,032
Income (loss) before taxes	$	(1,089,337	)	$	73,300		$	(1,016,037	)
Total assets	$	16,019,352		$	2,249,090		$	18,268,442
Property additions	$	19,708		$	-		$	19,708
Other income (expense)	$	3,271,339		$	-		$	3,271,339
Depreciation, depletion and amortization	$	(265,788	)	$	(97,869	)	$	(363,657	)


Three months ended November 30, 2010:	Oil & Gas				Gas Gathering				Consolidated
Revenues		$	38,569			$	4,670			$	43,239
Income (loss) before taxes		$	(525,926	)		$	(28,063	)		$	(553,989	)
Total assets		$	8,209,141			$	2,459,023			$	10,668,164
Property additions		$	179,396			$	-			$	179,396
Other income (expense)		$	59,682			$	-			$	59,682
Depreciation, depletion and amortization		$	(68,412	)		$	(32,623	)		$	(101,035	)


Three months ended November 30, 2009:	Oil & Gas			Gas Gathering			Consolidated
Revenues	$	44,511		$	25,200		$	69,711
Income (loss) before taxes	$	(676,802	)	$	78,630		$	(598,172	)
Total assets	$	16,019,352		$	2,249,090		$	18,268,442
Property additions	$	-		$	-		$	-
Other income (expense)	$	228,142		$	-		$	3,299,497
Depreciation, depletion and amortization	$	(29,243	)	$	(32,623	)	$	(61,866	)

Note 12 – Subsequent Events

On February 16, 2011, New Frontier Energy, Inc. (“NFE”) entered into a binding memorandum of understanding (MOU) with Emerald Oil and Gas, NL (“Emerald”) an Australian listed company (ASX: EMR) which provides for the following:

NFE will sell to Emerald the following assets (the “Assets”):

·	NFE’s leasehold interests located within Routt and Moffat counties, Colorado and Carbon and Sweetwater Counties, Wyoming,

·	any equipment or property used in connection with any oil and gas operations related to the assigned leases,

·	NFE’s limited partnership and general partnership interest in Slater Dome Gathering, LLLP,

·	NFE’s rights and claims under that certain Participation Agreement (as amended) between NFE and Entek GRB, LLC (Entek) dated on or about August 10, 2009,

·	NFE’s claims against Slaterdome Gas, Inc. pursuant to case file number 2010 CV 65 filed in the District Court in Moffat County Colorado, and

·	NFE’s claims against Slaterdome Gas, Inc. pursuant to case file number CV-10-202 filed in the District Court in Carbon County, Wyoming.

In addition, Emerald will assume all liabilities associated with the Assets except for environmental liabilities arising from the period prior to Closing Date.

The purchase price is USD 15,000,000 (Fifteen Million US Dollars) comprising of (i) AUD 5,000,000 (Five Million Australian Dollars) worth of free trading Emerald ordinary shares and (ii) the balance payable in cash in US dollars at Closing. Further, New Frontier has received certain undertakings relative to liquidity and value with respect to the shares of Emerald it will receive as part of the purchase price.

Conditions to closing include (i) the completion of due diligence by Emerald within 45 days of the MOU execution Date, (ii) Emerald shareholder approval of the transaction within 45 days of the MOU execution date; and (iii) Emerald’s completion of a capital raise within 50 days of the MOU execution date on terms acceptable to it, among others.

Management believes that the terms described herein are the relevant material terms of the MOU, however, there may be other terms and conditions in the MOU that other persons would consider material. Further disclosures will be forthcoming as and if necessary as negotiations and due diligence progress.

Due to the nature of the conditions to closing, it is not possible at this time to determine the likelihood that the transaction contemplated in the MOU will be concluded.

On March 1, 2011, the Board of Directors approved the payment of a cash award of $1,581,000 to the Chairman and CEO. The award provided for a clawback of up to $500,000 within a six-month period following the grant should a majority of the independent members of the Board of Directors determine that either the CEO has not performed in his role as CEO to the expectations of the voting board members or the Company requires such funds in order to maintain a prudent cash reserve level. The return of such funds will be payable within 10 business days from the date of the request.

Item 2. Management's Discussion and Analysis or Plan of Operation.

References to the “Company,” “us” or “we” refer to New Frontier Energy, Inc., a Colorado Corporation.

Information contained in the following discussion of results of operations and financial condition and in certain of the notes to the financial statements included in this document contain forward-looking statements within the meaning of the Private Securities Litigation Reform Act of 1995, which can be identified by the use of words such as “may,” “will,” “expect,” “anticipate,” “estimate,” or “continue,” or variations thereon or comparable terminology. In addition, all statements other than statements of historical facts that address activities, events, or developments the Company expects, believes, or anticipates will or may occur in the future, and other such matters, are forward-looking statements. The following discussion should be read in conjunction with the Company’s unaudited financial statements and related notes included elsewhere herein.

The Company’s future operating results may be affected by various trends and factors, which are beyond the Company’s control. The important factors that could prevent us from achieving our stated goals and objectives include, but are not limited to, those set forth in our Annual Report on Form 10-K for the fiscal year ended February 28, 2010 and the following:

·	The general state of the economy;

·	Our ability to successfully implement our plan of operations;

·	Our ability to raise additional capital, as it may be affected by general economic conditions, current conditions in the stock market and competition in the oil and gas industry for risk capital;

·	Environmental and other regulations, as the same presently exist and may hereafter be amended;

·	Our ability to identify, finance and integrate other acquisitions;

·	Volatility of our stock price; and

·	Actions of overseas producers of oil and natural gas over which we have no control.

We undertake no responsibility or obligation to update publicly these forward-looking statements, but may do so in the future in written or oral statements. Investors should take note of any future statements made by or on our behalf.

The Company cautions the reader that a number of important factors discussed herein, and in other reports filed with the Securities and Exchange Commission, including its 10-K for the year ended February 28, 2010, could affect the Company’s actual results and cause actual results to differ materially from those discussed in forward-looking statements. This information should be read in conjunction with our Annual Report on Form 10-K for the year ended February 28, 2010.

Overview

We are an independent energy company engaged in the exploration, development, acquisition, and production of natural gas and crude oil. Our operations are conducted entirely in the continental United States, principally in the Green River Basin (“GRB”) in Colorado and Wyoming, the Denver Julesburg Basin (“DJ Basin”) in Colorado and in the Calcasieu and Jefferson Davis Parishes in Louisiana (“Amazon Prospect”).

We use a variety of financial and operational measurements to analyze our operating performance. These measurements include: (i) production levels, trends and prices,(ii) operating expenses and general and administrative expenses and (iii) operating cash flow. These measurements are to be read in conjunction with “Management’s Discussion and Analysis of Financial Condition and Results of Operations” appearing in our Annual Report on Form 10-K for the fiscal year ended February 28, 2010.

The Participation Agreement

On August 10, 2009, we entered into a Participation Agreement (the “Participation Agreement”) with Entek GRB LLC (“Entek”) under which Entek agreed to purchase certain assets for $1.0 million and spend up to an additional $11.5 million over three years on exploration and development within approximately 66,000 gross acres (the “Underlying Leases”) to earn up to 55% of our interest in the Underlying Leases and certain other assets, including our partnership interests in Slater Dome Gathering, LLLP (collectively the “Assets”). We also created an area of mutual interest (the “Area of Mutual Interest”) with Entek in all lands located in Routt County, Colorado, Moffatt County, Colorado, Sweetwater County, Wyoming, and Carbon County Wyoming. Pursuant to the Area of Mutual Interest, Entek shall be entitled to participate for up to 55% in any additional interest acquired within the Area of Mutual Interest by us and we shall be entitled to participate for up to 45% in any additional interest acquired within the Area of Mutual Interest purchased by Entek.

Pursuant to the terms and conditions of the Participation Agreement, Entek had the right, after agreeing to proceed with Phase II (as defined in the Participation Agreement) of the Participation Agreement, to elect to become the operator of the Focus Ranch Unit and the Slaterdome Field. Entek made this election and effective May 1, 2010, we filed an assignment with the appropriate regulatory agencies naming Entek as operator of the Focus Ranch Unit and the Slaterdome Field.

Factors That Significantly Affect Our Financial Results

Revenue, cash flow from operations and future growth depend substantially on factors beyond our control, such as economic, political and regulatory developments and competition from other sources of energy. Natural gas and crude oil prices have historically been volatile and may be expected to fluctuate widely in the future. Sustained periods of low prices for natural gas and crude oil could materially and adversely affect our financial position, results of operations, and quantities of oil and gas that can be economically produced.

As of November 30, 2010 and 2009, there were no recoverable reserves from the Company’s wells in the Greater Green River Basin based upon the then current economic conditions, which primarily relate to the price of natural gas. In addition, there are no wells or recoverable reserves within the DJ Basin and Amazon prospect.

Recent developments

On June 4, 2010, we entered into a Purchase and Sale Agreement with Carrizo Oil & Gas, Inc. (“Carrizo”) to sell our interest in certain oil and gas leases (the “Leases”) in the DJ Basin in Weld and Morgan Counties, Colorado. We received proceeds of approximately $5.0 million (net of related transaction expenses) from the sale of the interest in the Leases.

Pursuant to the Purchase and Sale Agreement, Carrizo must drill not less than three Carry Wells (as defined in the Purchase and Sale Agreement) in the 18 months following the closing (the “Drilling Period”) on the sale of the interest in the Leases and carry us for a 33 1/3% working interest in each of these wells (subject to adjustment as provided in the Purchase and Sale Agreement). In the event that Carrizo fails to commence the drilling of the three Carry Wells during the Drilling Period, the Leases (except for a 640 acre tract) shall be reassigned back to us.

If Carrizo commences drilling three Carry Wells before the end of the Drilling Period, we have the option to re-acquire an undivided 1/3 working interest in the Leases. To reacquire the 1/3 working interest in the Leases, we shall pay 1/3 of to the total amount Carrizo paid to us to acquire the interest in the Leases, plus 1/3 of any amount Carrizo has paid to renew, extend or replace the Leases during the Drilling Period.

We also entered into an AMI Agreement with Carrizo, whereby both parties agreed to create an area of mutual interest in all governmental sections within which we own Leases as of June 4, 2010 (subject to certain exclusions) (the “AMI Territory”) and whereby each party granted the other party the option to acquire its proportionate interest, (33 1/3 in our case and 66 2/3 in the case of Carrizo) in any oil and gas leases and other interests within the AMI Territory.

As of November 30, 2010, there have been no wells drilled within this area and there are no proved reserves.

On September 1, 2010, we entered into a Joint Exploration Agreement (the “Agreement”) with Yuma Exploration and Production Company, Inc. (“Yuma”), whereby we will participate as a 10 percent working interest owner in the shooting, processing and interpretation of a 3-D seismic survey, the generation of prospects, the acquisition of leases, and the exploration, development and production of oil and gas prospects generated from the 3-D seismic in the Calcasieu and Jefferson Davis Parishes in Louisiana (Project Area”).

Results of Operation

The following tables reflect the components of our sales volumes, sales prices, operating revenue, costs and expenses for the nine and three month period ended November 30, 2010 and 2009.

	Nine month period
	ended November 30,
	2010		2009		$ Chg			% Chg
Sales volumes:
Natural gas sales (Mcf)		30,231		61,287		(31,056	)		(51	%)
Natural gas per day (Mcf/D)		110		223		(113	)		(51	%)

Average realized price ($Mcfe)	$	3.46	$	2.40	$	1.06			44	%

Net Sales:
Oil and gas sales	$	104,499	$	146,893	$	(42,394	)		(29	%)
Gas gathering income	$	399,172	$	113,139	$	286,033			253	%

Operating Expenses ($/Mcfe):
Exploration costs, including dry holes	$	638,176	$	76,411	$	561,765			735	%
Lease operating expenses	$	75,803	$	302,706	$	(226,903	)		(75	%)
Cost of gas gathering	$	-	$	2,235	$	(2,235	)		(100	%)
General and administrative	$	865,386	$	2,992,678	$	(2,127,292	)		(71	%)
Impairment expense	$	51,000	$	809,721	$	(758,721	)		(94	%)
Depreciation, depletion and amortization	$	270,108	$	363,657	$	(93,549	)		(26	%)
Other income (expense)	$	2,651,950	$	3,271,339	$	(619,389	)		(19	%)
Net income (loss) attributable to noncontrolling interest	$	65,166	$	26,977	$	38,189			142	%
Preferred stock dividends	$	175,971	$	562,825	$	(386,854	)		(69	%)

	Three month period
	ended November 30,
	2010			2009		$ Chg			% Chg
Sales volumes:
Natural gas sales (Mcf)		11,799			18,449		(6,650	)		(36	%)
Natural gas per day (Mcf/D)		130			203		(73	)		(36	%)

Average realized price ($Mcfe)	$	3.27		$	2.09	$	1.18			56	%

Net Sales:
Oil and gas sales	$	38,567		$	44,511	$	(5,944	)		(13	%)
Gas gathering income	$	4,669		$	25,200	$	(20,531	)		(81	%)

Operating Expenses ($/Mcfe):
Exploration costs, including dry holes	$	302,433		$	4,128	$	298,305			7226	%
Lease operating expenses	$	37,029		$	28,811	$	8,218			29	%
Cost of gas gathering	$	-		$	1,584	$	(1,584	)		(100	%)
General and administrative	$	216,413		$	799,636	$	(583,223	)		(73	%)
Impairment expense	$	-		$	-	$	-			-	%
Depreciation, depletion and amortization	$	101,035		$	61,866	$	39,169			63	%
Other income (expense)	$	59,682		$	228,142	$	(168,460	)		(74	%)
Net income (loss) attributable to noncontrolling interest	$	(9,170	)	$	13,933	$	(23,103	)		(166	)%
Preferred stock dividends	$	58,582		$	191,638	$	(133,056	)		(69	%)

Oil and Gas Sales

Our oil and gas sales decreased $42,394 or 29% to $104,499 during the nine month period ended November 30, 2010, compared to oil and gas sales of $146,893 during the nine month period ended November 30, 2009. During the three month period ended November 30, 2010, oil and gas sales decreased $5,944 or 13% to $38,567, compared to oil and gas sales of $44,511 during the three month period ended November 30, 2009.

The decrease in oil and gas sales for the nine month period is primarily attributable to decreased production from Slaterdome Field, which decreased 31,056 Mcf (113 Mcf per day) or 51%, compared to the same period in the prior year. Sales volumes during the three month period ended November 30, 2010, decreased 6,650 Mcf (73 Mcf per day) or 36% to 11,799 Mcf (130 Mcf per day), compared to 18,449 Mcf (203 Mcf per day) for the respective period in the prior year. The decline in production is primarily due to the current economic condition of the existing natural gas wells. Given the cost to operate these wells and the suppressed price of natural gas, we have shut-in several wells and are only producing those wells that require the least amount of maintenance.

The average sales price of natural gas sales for the nine and three month periods ended November 30, 2010, were $3.46 and $3.27 per Mcf, respectively, compared to $2.40 and $2.09 per Mcf, during the nine and three month periods ended November 30, 2009, respectively. This represented an increase for the nine and three month periods of $1.06 per Mcf or 44% and $1.18 per Mcf or 56%, respectively. The increase in the price of natural gas is a function of the general market conditions for natural gas.

Gas Gathering Income.

During the nine and three month periods ended November 30, 2010, SDG’s gathering fees from the Gas Gathering Pipeline were $399,172 and $4,669, respectively. This represented an increase of $286,033 or 253% for the nine month period and a decrease of $20,531 or 81% for the three month period, as compared to the respective periods in the prior year.

The increase in gathering fees for the nine month period can be attributed to the Participation Agreement with Entek and the annual shortfall payment associated with the construction cost reimbursement guarantee that is part of the gathering agreement between SDG and its working interest owners. As part of the gathering agreement, the working interest owners in the Slaterdome Field agreed to pay SDG a fee of $0.50 per million British Thermal Units (“MMBtu”) of gas transported through the line until two-thirds of the original construction costs amounting to $2,609,841 were recovered and $0.25 thereafter. This obligation ended on May 31, 2010, which resulted in a final shortfall payment of approximately $300,000.

Our portion of the gas gathering fees, including the annual shortfall payment, are included as Qualifying Development Expenses (as defined in the Participation Agreement) that are being carried by Entek in order to earn up to a maximum of 55% of our working interest. Prior to the Participation Agreement, our portion of the fees eliminated in consolidation, however, due to the Participation Agreement and the carry for these costs beginning in August 2009, they no longer eliminate upon consolidation and are recognized as gathering fee income in the consolidated financial statements.

The decrease in gathering fee income for the three month period ended November 30, 2010, can be attributed to the lower fee per MMBtu, which was reduced from $0.50 to $0.25 per MMBtu on May 31, 2010, due to the final shortfall payment related to the construction cost reimbursement guarantee discussed above and to decreased volumes.

Exploration Costs.

We incurred $638,176 and $302,433 in exploration costs during the nine and three month periods ended November 30, 2010. All of these costs can be attributed to the Agreement with Yuma related to the Amazon prospect. The majority of these costs were for 3-D seismic activity. Exploration costs incurred during the nine and three month periods ended November 30, 2009, were primarily made up of delay rentals, geologic and seismic consulting related to GRB.

Under the Participation agreement Entek will carry us on all geologic and geophysical costs, whereas, we participate and pay our pro-rata share of any delay rentals. Delay rentals are considered normal in the ordinary course of business.

Lease Operating Expense.

Lease operating expenses were $75,803 and $37,029 during the nine and three month periods ended November 30, 2010, respectively, as compared to $302,706 and $28,811 during the nine and three month periods ended November 30, 2009, respectively, representing a decrease of $226,903 or 75% for the nine month period ended and an increase of $8,218 or 29% for the three month period ended. The decrease in lease operating expenses for the nine month period is primarily attributable to the Participation Agreement with Entek, whereby Entek will carry us for 100% of Qualified Development Expenses. This agreement was in place during the full nine month period in the current year, whereas it was only in place for three months in the prior period. The lease operating expenses that we incurred during the three month period ending November 30, 2010, were consistent with the same period in the prior year, due to the Participation Agreement being in place for both comparative periods.

Gas Gathering Costs.

Gas gathering costs are related to the gathering system owned and operated by SDG. The gathering system services the Slaterdome Field and due to the decreased activity in this field there were no gathering costs incurred during the nine month period ended November 30, 2010, and only $2,235 of gathering costs incurred during the nine month period ended November 30, 2009.

General and Administrative Expense.

Our general and administrative (“G&A”) expense decreased $2,127,292 or 71% and $583,223 or 73% for the nine and three month periods ended November 30, 2010, as compared to the respective periods in the prior year. G&A expenses include both cash and non-cash charges. The decrease can be primarily attributed to non-cash charges, which decreased $1,754,425 or 86% and $564,446 or 99% during the nine and three month periods, respectively. Cash charges to G&A increased $127,133 or 13% and decreased $18,777 or 8% for the nine and three month periods, respectively.

Non-cash charges to G&A consist of bad debt expense and stock-based compensation arrangements associated with stock grants and stock option grants. We recognized $165,096 and $1,611 of stock-based compensation during the nine and three month periods ended November 30, 2010, compared to $2,042,820 and $566,058 during the nine and three month periods ended November 30, 2009.

Stock-based compensation charges in the current fiscal year include the amortization of the estimated fair value of options associated with 4,200,000 options issued during July 2008, which were fully amortized at May 31, 2010, and 500,000 options to acquire shares of the our common stock issued to our chief financial officer on May 11, 2010, exercisable at a price of $0.50 per share, an expiration date of December 31, 2011, and an estimated fair value of $30,600. Stock-based compensation reported in the respective periods in the prior year included the amortization of estimated fair value associated with the 4,200,000 options issued during July 2008, the estimated fair value associated with 1,250,000 options issued to our chairman on August 17, 2009, valued at $231,647, the estimated fair value related to 2,000,000 options that vested upon issuance to one of our director’s, valued at $420,351, the estimated fair value of $637,515 related to 2,056,500 shares of restricted common stock issued to our chairman as compensation for financial consulting services and as consideration for providing funds to be used as the segregated arbitration fund.

We recorded an allowance for bad debt of $123,297 for the nine month period ended November 30, 2010, related to one of our working interest owners. As of November 30, 2010, we have recorded a provision for doubtful accounts of $958,429 related to two working interest owners (see discussion on Slaterdome Gas, Inc. litigation in Note 10 – Legal Proceedings).

Cash G&A charges include professional fees, consulting fees, employee compensation and general office expense. G&A expenses decreased during the nine month period ended November 30, 2010, compared to the same period in the prior year. The decrease can be attributed to the Participation Agreement, employee compensation and general office expense. As part of the Participation Agreement that we entered into with Entek in August 2009, a portion of certain G&A costs were included as Qualified Development Expenses and reimbursed to us by Entek. In addition to the reimbursement of certain G&A costs, employee compensation decreased due to the change in the Company’s CFO and CEO. The former CFO resigned in August 2009, and the CFO position was filled in with contract CFO’s, whose costs are included in consulting fees. In November 2009, the former CEO resigned. The new CEO did not receive a cash salary during the nine month period ended November 30, 2010. In addition, on May 7, 2010, we assigned the operator status to Entek upon which occurrence four of our employees resigned from NFEI and joined Entek to assist with the transition and future operations.

Cash G&A expenses for the three month period remained flat, decreasing only $18,777 compared to the same period in the prior year, primarily due to the Participation Agreement being in place for the comparable periods.

Impairment Expense.

We recorded $51,000 and $809,721 of impairment expense during the nine month periods ended November 30, 2010 and 2009, respectively. The $51,000 impairment expense in 2010 was related to our Steamboat Property (asset held for sale), which is recorded at fair value less the costs to sell. The $809,721 impairment expense in the prior year is related to our unproved property, which was written down to fair market value using Level 3 inputs.

Depreciation, Depletion and Amortization Expense.

Depreciation, depletion and amortization was $270,108 and $101,035 during the nine and three month periods ended November 30, 2010, respectively, representing a decreased of $93,549 or 26% and an increase of $39,169 or 63% compared to $363,657 and $61,866 during the nine and three month periods ended November 30, 2009, respectively. We do not have any proved reserves, therefore our producing properties were all impaired and we did not record any depletion expense during the nine and three month periods ended August 31, 2010, and we only recorded depreciation and amortization expense related to our gathering facilities and other property, plant and equipment.

Other Income (Expense).

Other income (expense) includes the change in fair value of financial derivative instruments, interest income (expense) and gains (losses) on sales of assets. The following table represents the components of other income (expense):

	Nine month period
	ended November 30,
	2010			2009			$ Chg			% Chg
Other income (expense):
Change in fair value of derivative financial instruments	$	(40,000	)	$	3,220,000		$	(3,260,000	)		(101	%)
Other income	$	2,715,447		$	103,294		$	2,612,153			2528	%
Interest income (expense), net	$	(23,497	)	$	(51,955	)	$	28,458			55	%
Total other income (expense)	$	2,651,950		$	3,271,339		$	(619,389	)		(19	%)

	Three month period
	ended November 30,
	2010		2009			$ Chg			% Chg
Other income (expense):
Change in fair value of derivative financial instruments	$	30,000	$	150,000		$	(120,000	)		(80	%)
Other income	$	24,383	$	103,294		$	(78,910	)		(76	%)
Interest income (expense), net	$	5,299	$	(25,152	)	$	30,451			121	%
Total other income (expense)	$	59,682	$	228,142		$	(168,460	)		(74	%)

Derivative liability. On March 1, 2009, we adopted EITF 07-05: Determining Whether an Instrument (or Embedded Feature) is indexed to an Entity’s Own Stock (“EITF 07-05”). Upon its effectiveness, contracts (warrants, conversion features in debt, etc) that embody or embodied full-ratchet or reset provisions (that is, the strike, exercise or conversion prices adjust to pricing in subsequent sales or issuances of the Company’s common stock) no longer meet the definition of Indexed to a Company’s Own Stock and, accordingly, do not meet the exemptions for equity classification provided in ASC 815 Derivatives and Hedging (“ASC 815”). The Series B and Series C Preferred stock contain an anti-dilution provision which provides for conversion price adjustments (“down round protection”), which requires the embedded conversion feature to be bifurcated and presented separately as a derivative liability on the consolidated balance sheets. During the nine month period ended November 30, 2010, we recorded a loss of $40,000 and during the three month period ended November 30, 2010, we recorded a gain of $30,000 related to the change in the fair value of the derivative financial instruments, compared to recording gains of $3,220,000 and $150,000 during the nine and three month periods ended November 30, 2009. The primary reason for the change in valuation from the comparative periods is due to the conversion of the Series C Preferred stock on December 1, 2009, and the fluctuation in the closing price of our common stock.

Other income. Other income is the result of gains (losses) recognized for the sales of assets. We received proceeds of $5,070,296 from Carrizo, net of transaction costs related to the termination of a 2-D seismic licensing agreement with a third party, which required a one-time termination payment of $500,000, for the sale of our interest in the Leases located within the DJ Basin in June 2010. Pursuant to the agreement we have the option to re-acquire an undivided 1/3 working interest in the Leases, whereby, we shall pay 1/3 of to the total amount Carrizo paid to acquire the interest in the Leases plus 1/3 of any amount Carrizo has paid to renew, extend or replace the Leases during the Drilling Period.

In accordance with accounting standards generally accepted in the United States, we treated this option as a financing arrangement and recorded a gain on sale to the extent that two-thirds of the proceeds are recognized as proceeds received. The remaining one-third was treated as a financing arrangement, resulting in $1,856,766 being reflected as a deferred gain on the unaudited condensed consolidated balance sheet and as a financing activity in the unaudited condensed consolidated statement of cash flows within the condensed consolidated financial statements.

If this option is exercised, we will tender $1,856,766, plus 1/3 of any amount Carrizo has paid to renew, extend or replace the Leases during the Drilling Period to Carrizo in exchange for a 33 1/3 interest assignment in the Leases, and if the option expires unexercised, we will recognize an additional $1,856,766 as a gain on sale of unproved property.

Interest income (expense), net. During the nine month period ended November 30, 2010, we recorded $23,497 in interest expense, net of interest income earned. We paid off our Steamboat Mortgage in June 2010, which decreased our interest expense and we received $9,740 of interest income related to a $160,000 deposit that we had on account with Questar while we were the operator. The deposit and interest earned on the deposit was returned after we assigned the operator status to Entek.

Noncontrolling Interest.

Net income attributable to the noncontrolling interest related to the consolidated subsidiary, SDG, LLLP, was $65,166 and $26,977 during the nine month periods ended November 30, 2010 and 2009, respectively. This represented an increase of $38,189 or 142%. During the three month period ended November 30, 2010, SDG, LLLP recorded a net loss, which resulted in the noncontrolling interest being reduced $9,170. This fluctuation relates to the change in activity in SDG, such fluctuations are considered normal in the ordinary course of business. Distributions of approximately $74,000 were made in fiscal year 2009, while there have been no distributions made in the current fiscal year.

Preferred Stock.

Series B Convertible Preferred Stock. We charged dividends on the Series B Convertible Preferred Stock in the amount of $175,971 and $58,582 during the nine and three month periods ended November 30, 2010, respectively, against net income (loss) attributable to common shares. During the same periods in the prior year, we charged $155,975 and $57,007 against net income (loss) attributable to common shareholders.

Series C Preferred Stock. Effective December 1, 2009, the 216,000 outstanding shares of Series C Preferred Stock converted into an aggregate 34,099,265 shares of common stock pursuant to the automatic conversion provisions of the Series C Preferred Stock, therefore there were no dividends charged against net income (loss) attributable to common shares during the nine and three month periods ended November 30, 2010. During the nine and three month periods ended November 30, 2009, we charged $406,849 and $134,630 against net income (loss) attributable to common shares, respectively.

Liquidity and Capital Resources

In order to meet our goals and objectives, we will have to effectively invest capital into our existing projects and into new projects and acquisitions that are low to medium risk. We will need to seek additional capital, likely through asset sales and debt or equity financings, to continue our proposed operations. We can give no assurance that we will be able to raise such capital on such terms and conditions we deem reasonable, if at all. We will have limited financial resources until such time that we are able to generate such additional financing or additional cash flow from operations. Our ability to achieve profitability and positive cash flow is dependent upon our ability to exploit our oil and gas properties, generate revenue from our business operations and control our costs. Should we be unable to raise adequate capital or to meet the other above objectives, it is likely that we would have to substantially curtail our business activity or cease operating, and that our investors would incur substantial losses of their investment.

We expect that working capital requirements will be funded through a combination of our existing funds, asset sales, cash flow from operations, and issuance of equity and debt securities. Management believes that current cash balances will be sufficient to fund our capital and liquidity needs until at least February 28, 2012.

On June 4, 2010, the Company entered into a Purchase and Sale Agreement with Carrizo Oil & Gas, Inc. (“Carrizo”) to sell its interest in certain leases (“Leases”) in the DJ Basin. The Company received proceeds of approximately $5.0 million (net of related transaction expenses) from the sale of the interest in the Leases.

The following table summarizes the Company’s cash flows from operating, investing and financing activities and the amounts and percentage changes between years. The following analysis should be read in conjunction with our condensed consolidated financial statement of cash flows.

	November 30, 2010			November 30, 2009			Increase (Decrease)
Net cash used in operating activities	$	(1,712,337	)	$	(1,287,632	)	$	424,705 or 33%
Net cash used in investing activities	$	3,034,953		$	980,292		$	2,054,661 or 209%
Net cash used in financing activities	$	1,212,701		$	762,767		$	449,934 or 59%

Operating Activities

Cash used in operating activities increased $424,705 or 33% to $(1,712,337) during the nine month period ended November 30, 2010, compared to $1,287,632 used during the nine month period ended November 30, 2009. This is primarily the result of paying down the Company’s trade accounts payable, offset by collections made on accounts receivables and the refund of a deposit on account of $160,000. In addition, revenues from oil and gas production decreased. However, this decrease was offset by increased revenues from gathering activities, which are primarily the result of the annual shortfall fee (discussed in Note 8 – Commitments and also under Gas Gathering Income above), the Participation Agreement and reduced lease operating expenses and G&A expenses.

Investing Activities

During the nine month period ended November 30, 2010, investing activities provided cash of $3,034,953 compared to net cash provided by investing activities of $980,292 during the nine month period ended November 30, 2009, an increase of $2,054,661 or 209%. This increase is due to the Carrizo transaction in June 2004, which provided cash of $5,070,297 (net of transaction costs), of which $3,213,531 is reflected as an investing activity and the remaining $1,856,766 is reflected as a financing activity (See discussion above under the heading Other Income and in Note 3 - Acquisitions, Divestitures and Assets Held for Sale). The proceeds received from the sale were offset by cash expenditures for oil and gas properties located within the Amazon prospect related to the Joint Exploration Agreement with Yuma.

Financing Activities

Financing activities provided cash of $1,212,701 during the nine month period ended November 30, 2010, compared to net cash provided by financing activities of $762,767 during the nine month period ended November 30, 2009, an increase of $449,934 or 59%. The transaction with Carrizo is the primary responsibility for the increase. We categorized $1,856,766 of the $5,570,297 of proceeds received as financing activities during the nine month period ended November 30, 2010. This was offset by a cash payment of $635,000 in full satisfaction of the Steamboat note payable and an additional $9,065 for dividends related to the conversion of some Series B Preferred stock in to common shares.

Off-Balance Sheet Arrangements

We do not have any off-balance sheet financing arrangements or special purpose entities as of November 30, 2010. Accordingly, we are not materially exposed to any financing, liquidity, market or credit risk that could arise from these transactions if we had engaged in such financing arrangements.

Contractual Obligations

The following sets forth information with respect to our contractual obligations as of November 30, 2010.

	FY 2011		FY 2012		Thereafter		Total
Notes payable (1)	$	201,563	$	50,000	$	-	$	251,563
Office and lease equipment	$	1.313	$	16,765	$	1,405	$	19,483
Total	$	202,876	$	66,765	$	1,405	$	271,046

(1)	Includes the balance on the NRGG note payable of $201,563 and a note payable to an affiliate (director) of $50,000.

Critical Accounting Policies and Estimates.

We refer you to the corresponding section in Part II, Item 7 of our Annual Report on Form 10-K for the year ended February 28, 2010, and to the footnote disclosures included in Part I, Item 1 of this report.

Accounting Standards Update

Please see Note 2 - Basis of Presentation and Significant Accounting Policies under the heading Accounting Standards Update.

Item 3. Quantitative and Qualitative Disclosures About Market Risk

Oil and Gas Price Risk

Our primary market risk exposure is in the pricing applicable to our natural gas and oil production. Realized pricing is primarily driven by the prevailing worldwide price for crude oil and spot market prices applicable to our U.S. natural gas production. Pricing for natural gas and oil production has been volatile and unpredictable for several years, and we expect this volatility to continue in the future. The prices we receive for production depend on many factors outside of our control including volatility in the differences between product prices at sales points and the applicable index price. These factors include, but are not limited to: changes in market demands, the general state of the economy, weather, pipeline activity and capacity and inventory storage levels. We are not currently using derivatives at this time to mitigate the risk of adverse changes in commodity prices, however, we may consider using them in the future.

Item 4. Controls and Procedures

As of the end of the period covered by this report, an evaluation was carried out by New Frontier Energy, Inc., with the participation of our Chief Executive Officer and Chief Financial Officer, of the effectiveness of our disclosure controls and procedures (as defined in Rule 13a-15(e) under the Securities Exchange Act of 1934). Based upon that evaluation, our Chief Executive Officer and Chief Financial Officer concluded that these disclosure controls and procedures were not effective as of the end of the period covered by this report. In addition, no change in our internal control over financial reporting (as defined in Rule 13a-15(f) under the Securities Exchange Act of 1934) occurred during our most recent fiscal quarter that has materially affected, or is reasonably likely to materially affect, our internal control over financial reporting.

PART II--OTHER INFORMATION

Item 1. Legal Proceedings

For a description of legal proceedings in which the Company has been involved with during the current fiscal year, see the Company’s Form 10-K for the fiscal year ended February 28, 2010 filed with the Commission on December 7, 2010.

Item 1A. Risk Factors

Not Applicable.

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

Not Applicable.

Item 3. Defaults Upon Senior Securities.

Not Applicable.

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

Not Applicable.

Item 5. Other Information

On March 1, 2011, a disinterested member of the Board of Directors approved the payment of a cash award of $1,581,000 to the Chairman and CEO. The award provided for a clawback of up to $500,000 within a six-month period following the grant should a majority of the independent members of the Board of Directors determine that either the CEO has not performed in his role as CEO to the expectations of the voting board members or the Company requires such funds in order to maintain a prudent cash reserve level. The return of such funds will be payable within 10 business days from the date of the request.

Item 6. Exhibits

Exhibits: The following exhibits are filed with this report:

31.1	Certification pursuant to Rule 13a-14(a) or 15d-14(a) under The Securities Exchange Act of 1934 as amended.

31.2	Certification pursuant to Rule 13a-14(a) or 15d-14(a) under The Securities Exchange Act of 1934 as amended.

32.	Certifications pursuant to 18 U.S.C section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.

SIGNATURES

In accordance with the requirements of the Securities Exchange Act of 1934, as amended, the registrant caused this report to be signed on its behalf by the undersigned, thereunto duly authorized.

	New Frontier Energy, Inc.

Date: March 4, 2011	By:	/s/ Samyak Veera
		Samyak Veera, President and Chief Executive Officer



	By:	/s/ Tristan R. Farel
		Tristan R. Farel, Chief Financial Officer

NEW FRONTIER ENERGY INC - FORM 10-Q - March 7, 2011

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NEW FRONTIER ENERGY INC Reports